EPA-650/2-7 5-046
May 1975 Environmental Protection Technology Series
[VALUATION OF LOW-SULFUR
WESTERN COAL
CHARACTERISTICS, UTILIZATION,
AND COMBUSTION EXPERIENCE
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EPA-650/2-75-046
EVALUATION OF LOW-SULFUR
WESTERN COAL CHARACTERISTICS,
UTILIZATION, AND COMBUSTION EXPERIENCE
by
T.E. Ctvrtnicek, S.J. Rusek, andC.W. Sandy
Monsanto Research Corporation
Dayton Laboratory
1515 Nicholas Road
Dayton, Ohio 45407
Contract No. 68-02-1320, Task 12
ROAP No. 2IBBZ-008
Program Element No. 1AB013
EPA Project Officer: David G. Lachapelle
Control Systems Laboratory
National Environmental Research Center
Research Triangle Park, N. C. 27711
Prepared for
U.S . ENVIRONMENTAL PROTECTION AGENCY
OFFICE OF RESEARCH AND DEVELOPMENT
WASHINGTON, D. C. 20460
May 1975
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EPA REVIEW NOTICE
This report has been reviewed by the National Environmental Research
Center - Research Triangle Park, Office of Research and Development.
EPA, and approved for publication. Approval does not signify that the
contents necessarily reflect the views and policies of the Environmental
Protection Agency, nor does mention of trade names or commercial
products constitute endorsement or recommendation for use.
RESEARCH REPORTING SERIES
Research reports of the Office of Research and Development, U.S. Environ-
mental Protection Agency, have been grouped into series. These broad
categories were established to facilitate further development and applica-
tion of environmental technology. Elimination of traditional grouping was
consciously planned to foster technology transfer and maximum interface
in related fields. These series are:
1. ENVIRONMENTAL HEALTH EFFECTS RESEARCH
2. ENVIRONMENTAL PROTECTION TECHNOLOGY
3. ECOLOGICAL RESEARCH
4. ENVIRONMENTAL MONITORING
5. SOCIOECONOMIC ENVIRONMENTAL STUDIES
6. SCIENTIFIC AND TECHNICAL ASSESSMENT REPORTS
9. MISCELLANEOUS
This report has been assigned to the ENVIRONMENTAL PROTECTION
TECHNOLOGY series. This series describes research performed to
develop and demonstrate instrumentation, equipment and methodology
to repair or prevent environmental degradation from point and non-
point sources of pollution. This work provides the new or improved
technology required for the control and treatment of pollution sources
to meet environmental quality standards.
This document is available to the public for sale through the National
Technical Information Service, Springfield, Virginia 22161.
Publication No. EPA-650/2-75-046
11
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ABSTRACT
This report summarizes the data on western coal statistics,
combustion, and mining. Detailed information is presented
for coal occurrence, production, composition, and physical
and chemical properties. Discussions and economic analyses
are given as to the available mining techniques and trans-
portation modes to bring these vast coal reserves to large
fuel combustion markets. The effects of western coal
properties on combustion equipment operation and emissions
to the atmosphere are evaluated. The overall impact of
increased western coal production on the environment is
also analyzed and recommendations are made for further
investigation of problematic areas.
iii
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TABLE OP CONTENTS
Pag(
1. Conclusions and Recommendations 1
2. Introduction 11
3. Western Coal Utilization 13
3.1 Reserves and Resources 13
3.1.1 State Deposits 19
3.1.2 Principal Coalfield Resources 39
3.2 Mining Technology 43
3.2.1 Methods of Coal Mining 43
3.2.1.1 Underground Mining Methods 47
3.2.1.2 Strip Mining Methods 56
3.2.1.3 Auger Mining Methods 60
3.2.2 Methods of Coal Preparation 65
3.2.2.1 Ash Removal 66
3.2.2.2 Sulfur Removal 68
3.3 Coal Production/Consumption and Prices 68
P.O.B. Mine.
3.4 Considerations Affecting the Selection of 79
Western Coal Mine Sites
3-4.1 Western Coal Mining Economics 83
3.4.2 Western Coal Mining Technology 91
Forecast
3.4.3 Western Coal Mining Legislation 92
3.4.3.1 Existing Legislation - Surface 92
Mining
3.4.3.2 Existing Legislation - Under- 93
ground Mining
3.4.3.3 Recent Coal Lease Legislation 94
3.4.3.4 Recent and Pending Legislation- 94
Surface Mining
3.4.3-5 Recent and Pending Legislation- 96
Underground Mining
3.4.4 Evaluation of Western Coal Mining 96
Development Factors
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TABLE OF CONTENTS (Continued)
3.^.5 Water Requirements and Availability 97
3-5 Western Coal Composition and Assorted n4
Physical and Chemical Properties
3.6 Transportation Methods and the Cost of 130
Delivered Coals
3-6.1 Rail Method and Economics 133
3.6.2 Water Transport and its Applicability 146
3.6.3 Coal Slurry Pipeline Transport 150
Western Coal Combustion 159
4.1 Coal Firing Equipment 160
4.1.1 Underfeed Stokers l6o
4.1.1.1 Single Retort Stoker ]_60
4.1.1.2 Multiple Retort Stoker 164
4.1.2 Overfeed Stokers 169
4.1.3 Spreader Stokers 174
4.1.4 Water Cooled Vibrating Grate 181
Stokers
4.1.5 Pulverized Coal Furnaces , 184
4.2 Coal Burning Equipment Selection Guidelines 190
4.3 Boilers 190
4.3.1 Fire-Tube Boilers 194
4.3.2 Water-Tube Boiler 201
4.3-3 Fouling Characteristics 203
4.3.4 Corrosion of Boiler Tubes 212
4.4 Western Coal Combustion 214
Environmental Evaluation of Western Coal 223
Mining and Utilization
5.1 Environmental Aspects of Mining 226
5.2 Environmental Effects of Western Coal 234
Trace Elements
vi
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TABLE OP CONTENTS (Continued)
5.3 Sulfur Emission Characteristics 235
5.3.1 Total Sulfur 235
5.3.2 Sulfur Oxides 238
5.3.3 Coal Selection Criteria 243
6. References 255
Appendices 265
A Western Coal Reserves by Field 265
B Western Coalfield Descriptions 291
C Western Coal Production by Mine for 1972 and 351
1973 Including Coalseam/Active Mines Nomen-
clature Organization
D Current Utilization of Western Coals by User 391
Type
E Coal Prices F.O.B. Mine by County for 1972 401
F Federal and State Surface Mining Legislation 405
G Cost Analyses by County and Mine 419
H Pertinent Conversion Factors British to 553
International System of Units (SI)
vii
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LIST OP FIGURES
Figure
1 Coalfields of the Western United States 16
2 Coal Region Nomenclature 17
3 Black Mesa Coalfield of Arizona 24
4 Coalfields of Colorado 26
5 Coalfields of Montana 28
6 Coalfields of New Mexico 29
7 Coalfields of North Dakota 31
8 Coalfields of Oregon (Coos Bay Region) 33
9 Coal Area of South Dakota 35
10 Coalfields of Utah 36
11 Coalfields of Washington 38
12 Coalfields of Wyoming 40
13 Output Tonnage Per Man Per Shift at all Under- 45
ground Bituminous Coal Mines
14 Output Tonnage Per Man Per Shift at all 46
Surface Bituminous Coal Mines
15 Three Types of Entrances to Underground 48
Mines—Shaft, Slope and Drift
16 Basic Steps in Conventional Mining 50
17 Continuous Mining Machine 51
18 Idealized Panel Development Showing Method 52
of Working Places in Room-and-Pillar
Conventional Cycle
19 Plan View of Typical Longwall Layout 54
20 Longwall Mining Machine 55
21 Initial Pit Dimensions for Dragline Exposing 58
the Upper Rosebud Coal Seam
22 Dual Coal Auger 64
23 Coal Producing Districts of the United States 75
24 Average Annual Precipitation 99
vill
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LIST OP FIGURES (Continued)
Figure Page
25 Average Annual Pan Evaporation 100
26 Areas of Natural Water Surplus and 101
Natural Water Deficiency
2? Present Conventions in Water Rights Law 103
28 Water Supply and Demand in the Non-Coastal 104
Western States
29 Water Supply and Demand in the 48 106
Conterminous States
30 Water Resources Regions for Water Use in 107
the United States
31 Major Areas of Potential Ground Water 110
Development
32 Analysis of United States Coals Selected 116
to Represent the Various Ranks
33 Average Trace Element Content in Ash of Coal 121
From Three Areas Compared with Crustal Abundance
34 Trace Element Concentrations on Coal 123
35 Trace Elements vs Coal Ash Content 125
36 Regional Trace Element Distribution 127
37 Western Coal Distance to Major Markets 131
38 Existing Railroads in Relation to Markets 140
39 Average Relative Energy Transportation Costs 143
40 Waterways of the United States 148
41 Planned Great Lakes Route for Detroit-Edison 149
42 Map Showing Route of Black Mesa Coal Slurry 151
Line
43 Profile of Black Mesa Pipeline 152
44 Process Diagram of Preparation Plant and 154
One Pump Station (Black Mesa)
45 Coal Slurry Pipeline Transportation Costs 155
(1970)
46 Comparison of Alternate Modes of Energy 156
Transportation (1970)
ix
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LIST OP FIGURES (Continued)
Figure
47 Single Retort, Horizontal-Feed Side Ash 161
Discharge Underfeed Stoker
48 Multiple Retort Gravity-Feed Type of Rear 166
Ash Discharge Underfeed Stoker
49 Chain Grate Overfeed Stoker
50 Traveling Grate Spreader Stoker with Front 176
Ash Discharge
51 Reciprocating-Feeder Distributor and Over- 177
throw Rotor for Spreader Stokers
52 Water Cooled Vibrating Grate Stoker 183
53 Horizontal Return Tubular Boiler 195
54 Short Firebox Boiler
55 The Compact Boiler
56 Coal-Fired Scotch Boiler 200
57 Horizontal Straight-Tube Boiler 202
58 Type FF Integral-Furnace Boiler 207
59 Type FP Integral-Furnace Boiler 208
60 Type FH Integral-Furnace Boiler 209
61 Fly Ash Resistivity as a Function of 218
Temperature and Coal Sulfur Content
62 Resistivity as Function of Sodium Content 219
of the Fly Ash for a Group of Western Power
Plants
63 Relationship Between Total Sulfur Leaving 237
the Boiler, Boiler Capacity, Sulfur in
Fuel, and Heating Value of Fuel
64 S0x Rate as a Function of Boiler Size 239
65 Comparison of 9% Western and Eastern Coals 248
at 0% and 5% Sulfur in ASh
66 Minimum Sulfur Retention Required in Ash to 251
Meet S0x Standard of 1.2 Ib SO /106 Btu
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LIST OP TABLES
Table
1 Estimated Remaining Coal Reserves of the 15
United States, by Rank, Sulfur Content, and
State on January 1, 1965.
2 Demonstrated Coal Reserve Base of the Western 18
United States on January 1, 1974, by Method of
Mining
3 Demonstrated Reserve Base of Coals in the 20
Western United States on January 1, 1974,
Potentially Minable by Underground Methods
4 Demonstrated Reserve Base of Coals in the 21
Western United States on January 1, 1974,
Potentially Minable by Surface Methods
5 U.S. Bureau of Mines Classifications 22
Defining Quality of Resource Estimates
6 Principal Coalfields of the Western States 4l
7 Average Production of Bituminous Coal and 44
Lignite in the West Per Man Shift, I960
and 1966
8 Characteristics of Excavating and Haulage 6l
Equipment
9 Typical Capacities of Western Strip Mining 63
Equipment in 1973
10 Western Coal Cleaned Mechanically in 1972 67
11 Total State Coal Production, 1973 69
12 Annual Coal Production (1969-1972) with 71
Estimates for 1973, 1975, 1980, and 1985
13 Projected Coal Production from Federal Surface 72
Coal Mines for Steam Electric Plant Fuels for
1980-1981
14 Definition of Western Bituminous Coal and 74
Lignite Producing Districts
15 1973 Production and Consumption by State and 76
District of Origin
xi
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LIST OF TABLES (Continued)
Table Page
16 Coking Coal Produced in the Western States 77
with Major Coking Coal Seams in 1972.
17 Average Value of Bituminous Coal and Lignite, 78
F.O.B. Mines
18 Economic Cost Variables Influencing Grass 80
Roots Western Steam Coal Mining Development
19 Technological Variables Influencing Grass 8l
Roots Western Steam Coal Mining Development
20 Governmental Legislation Influencing Grass 82
Roots Western Steam Coal Mining Development
21 Estimated Capital Requirements for Surface 84
and Underground Western Coal Mines
22 Estimated Annual Production Costs for Sur- 86
face and Underground Western Coal Mines
23 Surface Coal Seam Thickness 88
24 Annual Natural Runoff 108
25 Existing and Emerging Water Management 111
Problems in the United States
26 Classification of Coals by Rank 115
27 Range of Coal Characteristics 117
28 Typical Ash Composition 119
29 Average Trace Element Content in Ash of 120
Coal from Three Areas, as Weight Percent
30 Average Trace Element Content in Ash of 124
Coals from Western States, Percent of Ash
31 Western Coal Tonnage by Method of Movement 132
32 Class I Railroads Serving Western Coal 135
Markets and Points East
33 Transportation Cost Characteristics of 139
Western Bituminous Coal Shipped to Selected
Consumers
34 Comparative Costs of Supplying Coal from 144
Western Producing Districts and Oil from
East Coast and Gulf Coast to Eastern and
Midwestern Markets
xii
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LIST OF TABLES (Continued)
Table Po
Page
35 Comparative Costs of Supplying High and Low 145
Sulfur Coal from Selected Producing Districts
to Selected Consuming Regions
36 Average Coal Freight Revenues for Rail and 146
Water, 1963 •
37 Population Breakdown by Burner Type of Coal- 159
fired Industrial Boilers in Service in the
U.S. (1973)
38 Heat Release Rate for Single Retort Under- 162
feed Stoker
39 Total Carbon Loss X65
40 Basic Design Criteria at Maximum Continuous 175
Rating
41 Hardgrove Grindability Index Range of Coals 187
42 Prevalent Pulverizer Exit Primary Air-Fuel 188
Temperature
43 Coal Purning Equipment Operating Character- 191
istics
44 Stoker Equipment Comparisons 193
45 Population Breakdown by Boiler Types 194
46 Summary Data from Ash Fouling Tests 204
47 Typical Ash Composition 206
48 Coal Ash Classification 211
49 Comparison of Western Coal and Typical 215
Illinois Coal
50 Study Needs, Coal Industry Development, 224
Northern Great Plains
51 Potential Land Disturbance in the Western 227
States and Selected Non-Western States
52 Emissions Data 24l
53 Sulfur Range in Coal Ash 249
xili
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SECTION 1
CONCLUSIONS AND RECOMMENDATIONS
1. The western states considered in this report and
having the greatest amount of demonstrated coal
reserves in decreasing order of tonnage are: Montana,
Wyoming, North Dakota, New Mexico, Colorado, Washing-
ton, South Dakota, Arizona, Utah, and Oregon. Over
200 billion tons of coal reserves have been demon-
strated in these states which represents more than
46$ of the total demonstrated coal reserves in the
United States.
2. From over 200 billion tons of demonstrated coal
reserves in the western states, over 43$ are surface
minable.
3. In terms of estimated coal reserves in the United
States, the western states account for about 16$ of
bituminous coal, 8l$ of sub-bituminous coal, and 98$
of lignite. The anthracite deposits are negligible
(less than 1$).
4. Eighty percent of sub-bituminous estimated coal
reserves and 91% of lignite estimated reserves in
the western states contain less than 1% sulfur.
5. The lowest rank coal, lignite, is generally found in
western North Dakota and part of eastern Montana. The
highest rank surface coal is found in the Southwest
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portions of Arizona and New Mexico. The highest
rank underground coal occurs in Utah and Colorado.
6. Coal mining operations in the West are mechanized to
a high degree due to the shortage of skilled labor.
The operations are also very large and efficient and
usually exceed U.S. average tonnage output per man
per shift in both underground and surface mines.
7. Typical mining operations in the West use either
underground or surface mining methods. Horizontal
auger mining is less common but is gaining acceptance
because it can recover the large amounts of coal left
in strip mine high walls.
8. Underground or deep mining is used in the West to
extract the higher quality bituminous coals such as
those used in coke manufacturing. The production of
underground mines is executed in one of two ways:
the traditional room-and-pillar system or the newer
longwall system.
9. Of the two basic methods of surface mining practiced
in the U.S., contour mining is less applicable to the
relatively flat or gently rolling topography of the
West. Area mining is the major strip mining method used
on western coal lands. Flat open pits developed may
range 100 feet wide and 1 mile long.
10. Underground coal mining costs usually center around
labor issues because of the large number of persons
required. Strip mining is largely equipment intensive
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(about 7^% of the capital investment costs).
Relatively large capital costs of underground pit
development is eliminated by strip mining. Despite
the high cost per ton of underground coal, the
underground mines can be competitive with strip
mines on a cost per Btu basis. Presently, the large
transportation costs to deliver western coals to the
major market areas are offset at the mine by low
overburden-to-coal ratio. The mining becomes im-
practical technically if the overburden thickness
is more than about 200 feet.
11. Approximately 10% of the total U.S. coal resources
lie within 150 ft of the surface (maximum economic
and practical stripping depth). This precludes strip
mining from a major role in the ultimate recovery of
American coal. In the long range the re-emergence
of underground mining methods may be expected.
Significant factors inhibiting the development of
new western coal mines today are legislative uncer-
tanties, high cost of meeting stringent reclamation
requirements, new mining equipment availability,
long haul transportation economics, skilled manpower
shortage, lack of new mining technology utilization,
and high capital investment.
12. A total of 109 coal mines produced nearly 58 million
tons of bituminous, sub-bituminous and lignite coals
marketed in the West in 1973. Their production amounted
to about 30 thousandths of 1/2 of demonstrated coal
reserves in the western states. Eighty-two percent of
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this production came from surface mines. Wyoming
is the leading state in the western coal production
followed by Montana and New Mexico. Almost 14 million
tons were produced in the state of Wyoming in 1973.
Montana produced almost 10 million and New Mexico
produced over 9 million tons in the same year.
13. The western states coal production estimates indicate
that the production will increase about 8.6 times
between 1972 and 1985.
14. Approximately 70% of the western coal produced stayed
in western producing districts.
15- P.O.B. mine prices of surface mined coal in the West
varied from $2.00 to $8.00 per ton in 1972, compared
to the U.S. average of $5.48 per ton. The cost of
underground coal ranged from $4.89 to $16.40 per ton
with the U.S. average at $9-70 per ton.
16. Approximately 21% of western coal production in 1972
was mechanically cleaned.
17- Although production of western coals is expected to
increase rapidly, it will be very dependent on
presently uncertain strip mining legislation.
18. The scarcity of water in most portions of the West
dictates that ground water be used to provide water for
coal mining and transporting. The Westwide Water
Study conducted by the Department of the Interior
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promises to generate a detailed information plan on
future water requirements in the West. The study will
be completed in 1977•
19. Considering overall ranges for coal properties, the
western coals are in the medium range of volatile
matter, in the lower range for fixed carbon, in the
higher range for moisture content, in the lower range
for caloric values, and the lower range of sulfur
content. Western coal deposits contain coals with
low as well as high ash contents.
20. Comparison of ash compositions in western coals and
eastern coals reveal that low sulfur-containing western
coals are also low in iron. However, generally higher
S03 content in the ash is observed with western coals
(Refer to Table 28). The western coals are also
2 to 4 times higher in average calcium and magnesium,
and 2 to 8 times lower in average potassium content.
Sodium content does not seem to follow any particular
trend, with the exception of North Dakota and Montana
coals which have relatively high sodium content of
4.4$ and 2.8%, respectively. Other U.S. coals range
in average sodium content between 0.1 and 1.7% as
Na20.
21. Total trace element content in western coals is nearly
the same as in other coals of the United States, but
the distribution of each element differ.s. Cadmium
and selenium are indigenous only to western coals.
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22. Rail methods comprising unit trains and common
carriers are currently the prime movers of western
coal. Rail rates up to 4.5
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26. The coal slurry pipeline is a proven coal transport
method. A 273 mile line hauling 5 1/2 million tons of
coal per year is being successfully operated by Black
Mesa Pipeline, Inc. Additional pipeline projects are
currently under study.
27. Considering the boiler steam capacity range between
10,000-500,000 Ib/hr, the underfeed stockers are pre-
dominant in 10,000-100,000 Ib/hr range, the spreader
stokers in 100,000-250,000 Ib/hr range, and the
pulverized coal firing in 250,000-500,000 Ib/hr range.
28. In most instances firing western coals in these boilers
designed for eastern or midwestern coals would result
in an increased carbon loss. Some derating of the
boiler capacity would also be needed for units presently
operating at full capacity.
29. Comparison of operation attributes rated the three
most widely used stokers in the following descending
order
-spreader
-chain and traveling grate
-underfeed
The traveling grate type was preferred over the
agitating grate type for all three stokers.
30. Both fire-tube and water-tube boilers are utilized up
to 22,000 Ib steam/hour boiler capacity. Only water-
tube boilers are used above this capacity.
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31. Boiler fouling rate increases rapidly with increasing
sodium content of ash at low sodium contents. The
fouling levels off when sodium content of ash reaches
8-10$. High calcium contents reduce the effect of
sodium on the deposition mechanism. To minimize
fouling requires reducing sodium content of ash to
levels as low as 1%.
32. No effect on boiler fouling rate was observed with
changes in the fuel moisture content and the percentage
of excess air. Fouling rate was increased markedly
with increasing temperature, especially between 800 and
1200°F, and 1800 and 2100°F.
33. Corrosion of the boiler tubes on the fire side is not
fully understood, but several chemical reaction
mechanisms have been proposed.
3^. Firing of western coal in equipment designed to burn
eastern or midwestern coal resulted in reduction of
boiler capacity due to western coal's lower heating
value and lower density. Existing coal feeding
mechanisms designed for more dense and higher quality
coal were the reasons for this reduction. A decline
in the collection efficiency of electrostatic
precipitators was also observed as a result of western
coal's low sulfur content and subsequent high fly ash
resistivity. Ash high sodium content and operation of
electrostatic precipitator at elevated temperature
(425°F) increase the fly ash resistivity to levels
comparable with those for high sulfur coal. High
coal moisture content will also reduce boiler efficiency,
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35. The fractions of state land areas that may potentially
be disturbed by coal mining in the western states are
generally orders of magnitude smaller than the frac-
tions observed in non-western states.
36. Pull reclamation of land in strip mined areas of the
West is expensive and has been practiced to some extent
with mixed success. Most serious problems include
backfill of huge mined-out pits, topsoil replacement,
and revegetation in these semi-arid and arid regions.
Longwall stripping is a promising new surface mining
concept resulting in minimum damage of the environment
and the soil surface.
37. Hazardous emissions of the particulates accompany
coal mining operations. Additional airborne particu-
lates and noxious gases are emitted from wind erosion
and self-igniting refuse piles. Presently, these
emissions are not well documented and technology for
their control is not generally available.
38. There is insufficient information to assess the effect
of western coal trace element composition on the
environment. Additional work to investigate the form
and fate of these elements in the environment as well
as their hazard potential is urgently needed.
39. The low-sulfur emissions characteristics of western
coals are penalized by their lower heating values.
That is, more western coal must be burned to maintain
the same boiler heat rate obtained with non-western
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coal. However, available data indicate that low-
sulfur western coal burning plants in the small and
intermediate boiler size range examined generally
meet the Federal S02 regulation (1.2 Ib S02 per 106
Btu). None of the non-western coal burning plants
examined which burned high-sulfur high heating value
coals met the S02 emission regulation.
40. As coal sulfur content decreases increased sulfur
retention in the coal ash becomes important in reducing
SO emissions. Western coals characteristically
J\
appear to retain more sulfur in ash (21% max as 803)
than their nonwestern counterparts (10% max as 803).
This is in part due to the higher alkalinity of
western coal ash.
4l. Whether or not a specific coal meets the S02 emission
standard depends on coal heating value, coal ash
content, coal sulfur content and the previously
mentioned sulfur content of the ash after combustion.
A relationship comprised of the above variables which
could be used to define the minimum sulfur retention
in the coal ash in order for the coal to meet the sulfur
emission standard is proposed for verification.
10
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SECTION 2
INTRODUCTION
One of the potential means of sulfur oxides emission con-
trol from combustion sources is the use of low sulfur fuels.
Vast reserves of coal with large portions containing per-
missible sulfur levels occur in western parts of the United
States. These coal deposits are often easily accessible
and subject to strip mining, but usually have low heat
content, and high ash and water contents. Other properties
such as ash fusion temperature, trace element contents and
Hardgrove grindability index also have important effects
on combustion processes, efficiency of combustion equipment,
and properties of combustion gases emitted to the atmosphere.
In order to better define the technical, economic, and
environmental problems that may arise should an extensive
utilization of western coal reserves occur, the Environmental
Protection Agency contracted with Monsanto Research Corpora-
tion to conduct this study. The objectives of the study
were to summarize present experience in the combustion of
western coals, catalog their occurrence and properties,
and identify potential problematic areas in bringing these
coals to large markets. This report documents the results
of the study.
After the summary of findings and recommendations in the
previous section, the report presents data on utilization of
western coal in Section 3- This section includes information
11
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on western coal reserves and resources, mining technology,
production and consumption, composition, factors influencing
mining, and transportation. Section 4 evaluates western
coal combustion and Section 5 presents information on the
environmental effects associated with western coal mining
and combustion.
12
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SECTION 3
WESTERN COAL UTILIZATION
3.1 RESERVES AND RESOURCES
This report covers the ten states listed below which are
deemed important to the development of western coal pro-
duction:
Arizona Oregon
Colorado South Dakota
Montana Utah
New Mexico Washington
North Dakota Wyoming
Although Oregon and South Dakota have the least coal in
terms of potentially minable reserves, they are included
for completeness.
The following nine western states are not considered
important for fundamental coal development due to a lack
of resources, high sulfur content, or uneconomical dis-
tance of hauling to midwestern markets:
Alaska Nebraska
California Nevada
Idaho Oklahoma
Kansas Texas
Missouri
13
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Table 1 gives some indication of the relative merits of
the considered states from a low sulfur standpoint. The
arrows on Table 1 point to the ten states included in the
study. A majority of sub-bituminous coal and lignite with
0.1% or less sulfur is contained in these states.
Figure 1 shows the major coal regions of the western
states. The nomenclature of these coal regions is defined
in Figure 2. Table 2 shows that over 200 billion tons of
potentially minable coal occur in the ten western states
considered in this report. Of this quantity, 87 billion
tons are considered surface minable and 114 billion tons
are considered minable by underground methods. The state-
by-state ranking in decreasing order of demonstrated
reserve tonnage in millions of short tons is as follows:
1) Montana (107,727, 2) Wyoming (51,228), 3) North Dakota
(16,003), 4) Colorado (14,870), 5) New Mexico (4,394), 6)
Utah (4,042), 7) Washington (1,954), 8) South Dakota (428),
9) Arizona (350), and 10) Oregon (1). Over 46% of the
entire U.S. reserve base is located in the 10 states
included in this study.
A coal reserve differs from a coal resource. Coal reserves
represent calculated, potentially minable tonnages, whereas
coal resources represent total in-place tonnages of coal.
All coal resources may not be presently considered minable
due to some physical restrictions such as thin seams.
Thickness criteria used by the Bureau of Mines to compute
the reserve values given in Table 2 are 28 inches or more
for bituminous coal and anthracite, and 60 inches or more
for subbituminous coal and lignite. The maximum depth for
14
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Table 1. ESTIMATED REMAINING COAL RESERVES OF THE
UNITED STATES BY RANK SULFUR CONTENT, AND STATE,
ON JANUARY 1, 1965!
Coal rank & State
Bituminous coal:
Alabama
Alaska
Arkansas
Colorado
Georgia
Illinois
Indiana
Iowa
Kansas
Kentucky :
West
East
Maryland
Michigan
Missouri
Montana
New Mexico
North Carol Ina
Ohio
Oklahoma
Oregon
Pennsylvania
Tennessee
Texas
Utah
Virginia
Washington
West Virginia
Wyoming
Other States*
Total
Percent of tota!
oubbi turn! nous coal :
Alaska
Colorado
Montana
New Mexico
Oregon
Utah
Washington
Wyoming
Other Statesb
Total
Percent of total
Lignite:
Alabama
Arkansas
Montana
North Dakota
South Dakota
Texas
Washington
other Statesd
Total
Percent of total
Alaska
Arkansas
Colorado
New Mexico
Pennsylvania
Virginia
Washington
Total
Percent of total
Percent of total
(Million short tons)
Sulfur content, percent
6.7 or less
889.2
20,287.11
....
25,178.3
197.5
13,639-9
_-_
- —
51-2
5,212.0
- —
...
250.6
44.0
3.3
—
8,551.1
1,981.5
898.9
20,761.0
6,222.2
101,168.1
I4.ll
71,115.6
13,320.8
94,084.1)
38,735.0
87.0
— _
3,693.8
35,579.7
556,616.3
66.0
—
280.0
60,214.5
284,129.1
311,623.6
77.0
2,101.0
12,211.0
335.0
5.0
11,652.0
96.5
45.7
o.a-i.,. 7
100.0
aArizona, California, Idaho, Nebraska, Nevada
^Arizona, California, Idaho
cLesa than 0.1 percent
dCallfornla, Idaho, Louisiana, Nevada
'Nielsen, 0. P. 1973 Keystone Coal Industry Manual.
1973. p. 659.
New York, Mc<3raw-Hill, Inc.
15
-------
0 N
0 F
3867-10
• NORTHERN /
I GREAT / D««ot« I
.^.S.« / . J~ J
-• ^— \
Figure 1. Coalfields of the western United States2
2Anon. Strippable Reserves of Bituminous Coal and Lignite
in the United States. Bureau of Mines Information Circular
8531. 1971. P- 6.
16
-------
' WM^ i
J— -7—- Jfe
I rjRKeiQ
•
EXPLANATION
Medium and high-volatile bituminous cool
Subbituminous coal
Lignite
Figure 2. Coal region nomenclature3
3Link, J. M., and A. M. Keanan. A Review of the Coal Industry
in the Western United States. Colorado School of Mines,
Mineral Industries. Bulletin No. 5. 1968. p. 6.
17
-------
,a
Table 2. DEMONSTRATED COAL RESERVE BASE OF THE WESTERN
UNITED STATES ON JANUARY 1, 1974, BY METHOD OF MINING1*
(million short tons)
State
Arizona
Colorado
Montana
New Mexico
North Dakota
Oregon
South Dakota
Utah
Washington
Wyoming
Total western
states
Total U.S.
Potential mining method
Underground
14,000
65,165
2,136
1
3,780
1,446
27,554
114,082
297,235
Surface0
350
870
42,562
2,258
16,003
(b)
428
262
508
23,674
86,915
136,713
Total
350
14,870
107,727
4,394
16,003
1
428
4,042
1,954
51,228
200,997
433,948
Includes measured and indicated categories as defined by
the USBM and USGS and represents 100% of the coal in-
place
}Less than 1 million tons
'Overburden thickness less than 1000 ft
^Murphy, Z. E., E. T. Sheridan, and R. E. Harris,
Demonstrated Coal Reserve Base of the United States
on January 1, 1974. Mineral Industry Surveys. Bureau
of Mines Division of Fossil Fuels—Mineral Supply.
June 1974. p. 4.
18
-------
all ranks except lignite Is 1000 feet. Lignite reserves
are not considered at depths over 120 feet. Currently-mined
coal beds which do not meet the above criteria are included
in the estimate. Tables 3 and 4 show a further breakdown
of these potential reserves by coal rank and by mining
method. (Refer to Table 26 for the definition of coal rank.)
The portion of the in-place potential reserves that can be
recovered depends on the exact mining methods characteristic
to a specific coalfield. The amount of coal that can be
recovered generally ranges from 40 to 90%- ** The low side
of this range represents underground mining and the high
side represents strip area mining or strip/auger combinations,
Significant changes in the demonstrated coal reserve base
can occur. Results of new explorations and mining develop-
ments can add to the base, and mining production can decrease
it. The demonstrated coal reserve base represents the most
accurate estimate available, since it is a compilation of
all known deposits. The quality of the reserves reported by
the Bureau of Mines and Geological Survey is outlined by the
various measured, indicated and inferred categories defined
in Table 5-
3.1.1 State Deposits
The following is a brief description of major coal deposits
found in the western states. It will become evident that
coal tonnages differ in some instances from those shown in
Tables 2, 3, and 4. This results because the estimates for
the individual states are largely inferred, and those that
are calculated have overburden thicknesses over 1000 feet.
19
-------
Table 3. DEMONSTRATED RESERVE BASEd OP COALS IN THE
WESTERN UNITED STATES ON JANUARY 1, 1974, POTENTIALLY
MINABLE BY UNDERGROUND METHODS4
(million short tons)
State
Colorado
Montana
New Mexico
Oregon
Utah
Washington
Wyoming
Total
western U.S.
Total U.S.
Anthra-
cite
28
2
30
7,294
Bitumi-
nous
9,227
1,384
1,527
3,780
251
4,524
20,693
194,336
Sub-
bituminous
4,745
63,781
607
1
"1,195
23,030
93,359
97,605
Lignite
Total
14,000
65,165
2,136
1
3,780
1,446
27,554
114,082
297,235
a
Includes measured and indicated categories as defined by
the USBM and USGS and represents 100/5 of the coal in-place
5-
20
-------
Table 4. DEMONSTRATED RESERVE BASEa OP COALS IN THE
WESTERN UNITED STATES ON JANUARY 1, 1974, POTENTIALLY
MINABLE BY SURFACE METHODS ">
(million short tons)
State
Arizona
Colorado
Montana
New Mexico
North Dakota
Oregon
South Dakota
Utah
Washington
Wyoming
Total western
states
Total U.S.
Anthra-
cite
90
Bitumi-
nous
870
250
(b)
262
1,382
40,561
Sub-
bituminous
350
35,431
2,008
(b)
500
23,674
61,963
67,865
Lignite
7,131
16,003
428
8
23,570
28,197
Total
350
870
42,562
2,258
16,003
(b)
428
262
508
23,674
86,915
136,713
o
Includes measured and indicated categories as defined by
the USBM and USGS and represents 100$ of the coal in-place
Less than 1 million tons
'p. 6.
21
-------
Table 5. U.S. BUREAU OF MINES CLASSIFICATIONS
DEFINING QUALITY OF RESOURCE ESTIMATES5
Measured ore. Ore for which tonnage is computed from
dimensions revealed in outcrops, trenches, workings, and
drill holes and for which the grade is computed from the
results of detailed sampling. The sites for inspection,
sampling, and measurement are so closely spaced and the
geologic character is so well defined that the size, shape,
and mineral content are well established. The computed
tonnage and grade are judged to be accurate within limits
which are stated, and no such limit is judged to differ
from the computed tonnage or grade by more than 20 percent.
Indicated ore. Ore for which tonnage and grade are computed
partly from specific measurements, samples, or production
data and partly from projection for a reasonable distance on
geologic evidence. The sites available for inspection,
measurement, and sampling are too widely or otherwise in-
appropriately spaced to outline the ore completely or to
establish its grade throughout.
Inferred ore. (a) Ore for which quantitative estimates are
based largely on broad knowledge of the geologic character
of the deposit and for which there are few, if any, samples
or measurements. The estimates are based on an assumed con-
tinuity or repetition for which there is a geologic evidence;
this evidence may include comparison with deposits of similar
type. Bodies that are completely concealed may be included
if there is specific geologic evidence of their presence.
Estimates of inferred ore should include a statement of the
special limits within which the inferred ore may lie. (b)
Used essentially in the same sense as possible ore and
extension ore.
5Thrush, P. W. A Dictionary of Mining, Mineral, and Related
Terms. Washington, U.S. Department of the Interior, Bureau
of Mines. 1968. pp. 575, 578, 688.
22
-------
More detailed statewide coal resource information as
derived from open file and related literature may be found
in Appendix A. In all cases the demonstrated coal reserve
tonnages (Tables 2, 3 and 4) are the more accurate figures.
Figures for estimated resources were included to indicate
coal resource potential.
Arizona (350 MMT Demonstrated Reserves)
Arizona's primary known coal deposits are inferred to
approximate one billion tons under 130 feet of overburden.
These deposits are located in the northeast corner of
Arizona under 3200 square miles of Navajo and Hop! Indian
Reservation land1 called the Black Mesa Region. It occupies
portions of Navajo, Apache, and Coconino countries (see
Figure 3). Other coal bearing areas in the state appear
insignificant.
Coal rank is generally considered bituminous but borders
on subbituminous (refer to Table 26 for coal rank definition)
Variations have been reported ranging on either side of the
line that separates subbituminous from bituminous coal.
Pierce and Wilt (1970) concluded that the coals of the Black
Mesa Field are high-volatile (bituminous).1 The U.S. Bureau
of Mines classed strippable reserves as subbituminous.1
Nearly all of the Black Mesa coal is unsuitable for coking.
Most of the Black Mesa coal is considered surface minable,
but Peirce and Wilt estimate another 20 billion tons may lie
within 1700 feet of the surface or less, largely less. How
23
-------
114
Figure 3. Black Mesa coalfield of Arizona1
. 452.
-------
much of this coal Is available for underground mining is
unknown. Coal seam thickness ranges from 5 to 28 feet in
the surface minable portions of the field.
Colorado (14,870 MMT Demonstrated Reserves)
Colorado coal occurs in most parts of the state with the
exception of the entire eastern border. Approximately
29,600 square miles in 32 counties is underlain by coal
bearing rocks (see Figure 4).1 A grand total of 230
billion tons of original in-place coal resources is esti-
mated for the 20 major coalfields in the eight coal
bearing regions to depths of 6000 feet.1 These eight
regions and 20 coalfields are also identified in Figure 4.
Coal rank ranges from high-volatile B bituminous in the
older coal bearing groups of the San Juan Region to sub-
bituminous C and lignite in the younger formations of the
Denver Basin and Green River regions. (Refer to Table 26
for coal rank definition.) Some anthracite exists but it
is less than 1% of the total resources. It is estimated
that half of the Colorado resources are classed as high-
volatile bituminous with coking qualities.6
About 95% of Colorado's coal resources must be mined under-
ground because of complex structural geology.1 Folds,
faults, and igneous intrusions make conventional surface
mining difficult and uneconomical. Underground coal seam
thickness varies but can exceed 34 feet in areas of the
Uinta Region.
XPP. 455, 467, 456.
6Robeck, R. C. Colorado: Energy Shortages Prompt New Look
at Potential Coal Markets. Coal Age. 79:80, May 1974.
25
-------
106'
~^^jn..r\
• »coo«ic« ,
mi.
n
-------
Montana (107,727 MMT Demonstrated Reserves)
Coal bearing areas cover about 35% or 51,500 square miles
of the state. Coal resources are thought to be 378 billion
tons to depths of 6000 feet.1 Coal occurs in the 10 re-
gions or fields presented in Figure 5. Subbituminous coal
and lignite are the. primary types of coal found in Montana.
(Refer to Table 26 for coal rank definition.) Bituminous
coal also exists in several regions across the state. Vast
lignite resources occur in the eastern end, forming part of
the North Dakota/Montana lignite regions.
Although there are vast underground reserves, current mining
method economics dictate that coal be surface mined. Sub-
bituminous coal resources are currently being mined in the
southeastern portion of the Port Union Region. The state
is well known for its thick coal seams. Seam thicknesses
of 90 feet and upwards are not uncommon in some areas.1
New Mexico (4.39*1 MMT Demonstrated Reserves)
Coal occurs mainly in the northwestern section of the state.
About 25,000 square miles of New Mexico are underlain by
coal beds at depths of more than 5000 feet.1 An estimated
283 billion tons of both surface and deep minable coal
resources exist.1 The regions, areas and fields comprising
New Mexico's coal resources are shown in Figure 6.
JPP. 498, 499, 503, 510.
27
-------
L \ /X7'. ; J
/'v';>^;^,.or''rv
SUBBITUMINOUS LIGNITE
COAL
•J
3867-11
COAL REGIONS/FIELDS
Port Union Region
Bull Mountain Field
Red Lodge Field
Great Falls-Lewistown
North Central Region
Blackfeet-Valier Field
Electric Field
Livingston-Trail Creek Field
Lombard Field
Western Region Fields
Figure 5- Coalfields of Montana1
. 498.
28
-------
C 0 L 0 RA D 0
CERRILLOS* i
FIELD. T 5-W MIGUEL
'O «|fc » ;
UERCO **-UNA DEL GATO HEL
t~ - H Of BACA \ \ J x
- « ^ l **
SOCOKRO
-
I
L _______ I ---- A-
TEXAS
MEXICO
3867-12
greottr than 1,000 ftet
aK=KZ^^^K==s^HHi ' " Subbitumlnous coal Isolated cogl outcrop
COAL REGIONS/AREAS/FIELDS
San Juan Basin Region
Raton Field
Cerrillos Field
Una del Gato Field
Tijeras Area
Datil Mountain Area
Carthage Field
Jornada del Muerto Area
Sierra Blanca Field
Engle Area
Figure 6. Coalfields of New Mexico1
. 503.
29
-------
Coals range from subbituminous B to anthracite in rank,
but in general are in the range from subbituminous A to
high-volatile C bituminous.1 (Refer to Table 26 for coal
rank definition.) Rank depends primarily on intrusion of
igneous rock masses and structural deformation rather than
age metamorphism.
Stripping is currently the primary method of mining the coal
resources. High quality coking coal in the Raton Field area
is encouraging underground activity. Strippable coal seams
upwards of 50 feet thick occur in the San Juan Basin Region. J
North Dakota (16,003 MMT Demonstrated Reserves)
North Dakota's coal resources fill the entire western por-
tion of the state (see Figure 7). The coal bearing areas
occupy 28,000 square miles or approximately 40$ of the state
The estimated total resource is 351 billion tons.1 Large
portions of coal in North Dakota are considered removable by
surface methods and, thus, represent large strippable re-
serves. Estimates have been made of 32 billion tons to a
depth of 100 feet. This is based upon the total reserves
inferred to be present.1 The major coal deposits are those
listed in Figure 7-
All coal in the major coal deposits is lignitic. Lignite
is characterized by high moisture content and low heating
value. Analyses of lignite throughout the major deposits,
ipp. 504, 505, 511, 512
30
-------
SOUTH DAKOTA
COAL DEPOSITS
(1) Noonan-Kincaid
(2) Niobe
(3) Avoca
(4) M & M
(5) Velva
(6) Washburn
(7) Wilton
(8) Renner's Cave
(9) Hazen
(10) Beulah-Zap
(11) Stanton
(12) Center
(13) Dunn Center
(14) Dickinson
(15) Beach
(16) Bowman-Gascayne
Figure 7. Coalfields of North Dakota7
7Pollard, B. C., J. B. Smith, and C. C. Knox. Strippable
Lignite Reserves of North Dakota. - Location, Tonnage and
Characteristics of Lignite and Overburden. Bureau of
Mines Information Circular. 8537. 1972. p. 3.
-------
however, show considerable variation in moisture, ash
content, ash softening temperature, and heating value.
(Refer to Table 26 for coal rank definition.)
The current trend has been to surface mine these coals
because of the low market value and low Btu content. Seam
thickness generally runs from 5 to 12 feet.
Oregon (1 MMT Demonstrated Reserves)
Sparse, widely distributed amounts of coal occur in Oregon.
However, due to the severe power shortage in the Pacific
Northwest, Oregon is included as an energy source to be
examined. Resources of one billion tons are estimated to
exist to depths of 6000 feet in the major coalfield, Coos
Bay (see Figure 8).8 Measured, indicated, and inferred
estimates total nearly 66 million tons for a portion of the
coal field to a depth less than 1500 feet.9
Coal in the Coos Bay field is subbituminous B, subbituminous
C, or lignite. (Refer to Table 26 for coal rank definition.)
Sulfur content is slightly higher than for other states con-
sidered in this report, 0.5 to 5-0$ averaging less than 2.0%.
No coal is currently being mined in Oregon. Previous mining
operations were underground and were abandoned due to the
discovery of gas and oil in California. Small quantities
of surface minable coal exist. Average coal seam thickness
is approximately 5 feet.9
8Geer, M. R. Oregon. Coal Age. ?8(5):l49, April 1973.
9Mason, R. S., and M. I. Erwin. Coal Resources of Oregon.
United States Geological Survey Circular. 362. 1955,
pp. 3, 2.
32
-------
COAL DEPOSITS
(1) Southport and Thomas
(2) South Slough
(3) Englewood
(4) Riverton
(5) Beaver Slough
(6) Lillian
Area including reserves
estimated by Allen and
Baldwin, 19^4
Area including reserves
estimated by Duncan, 1953
Figure 8. Coalfields of Oregon (Goes Bay region)
8p. 150
33
-------
South Dakota (428 MMT Demonstrated Reserves)
Lignitic coal occurrence in South Dakota is entirely in the
northwestern portion of the state. Some 7000 to 8000 square
miles of land are underlain by potentially coal bearing rock
(see Figure 9). This area is an extension of the Montana
and North Dakota lignite deposits. Estimates of strippable
resources range from a half billion to more than one billion
tons.10 Firm estimates are sparse due to limited exploration
Most coal in South Dakota is lignitic. A small amount of
the coal is of a sub-bituminous grade but it is not commer-
cially important. (Refer to Table 26 for coal rank defini-
tion. )
Future large-scale development is uncertain due to coal
seams which are relatively thin and lenticular. If develop-
ment is pursued, mining trends should follow the large-scale
surface operations in North Dakota.
Utah (4,042 MMT Demonstrated Reserves)
Coal bearing rocks underlie over 3^00 square miles of the
state to depths of 3000 feet. Mapped and explored estimates
indicate that some 32 billion tons of coal occur throughout
the state to this depth. Utah's coal occurs in the 19
fields presented in Figure 10.l Over 99% of the mapped and
explored coal is bituminous, with the balance subbituminous.
(Refer to Table 26 for coal rank definition.) High quality
coking coals are widespread and abundant in Utah.
10P. 157.
xp. 536.
-------
Figure 9. Coal area of South Dakota10
10Noble, E. A. South Dakota. Coal Age. 78(5):157,
Mid April 1973.
35
-------
3867-13
COAL FIELDS
(1) Alton
(2) Kaiparowits Plateau
(3) Kolob-Harmony
(M) Mount Pleasant
(5) Salina Canyon
(6) Sterling
(7) Wales
(8) Wasatch Plateau
(9) Book Cliffs
(10) Emery
(11) Vernal
(12) Henry Mountains
(13) Sego
(14) LaSal-San Juan
(15) Tabby Mountain
(16) Coalville
(17) Henry's Pork
(18) Goose Creek
(19) Lost Creek
Figure 10. Coalfields of Utah1
. 536.
36
-------
Nearly all of the state's reserves are minable only by
underground methods1. New areas are being explored which may
preclude underground mining in favor of surface mining.
Seam thickness can reach 10 feet or more. Nearly all current
operations are in beds with thicknesses greater than 8 feet.1
Washington (1,954 MMT Demonstrated Reserves)
Coal occurs in scattered amounts throughout the state but
is primarily concentrated along the western foothills of
the Cascade Mountains. Estimated reserves of all ranks of
coal to depths of 3000 feet by measured, indicated, and
inferred categories are over six billion tons.1 Twelve
coal bearing areas in Washington State are identified in
Figure 11.
Coal ranks from lignite to bituminous with the majority
being subbituminous. (Refer to Table 26 for coal rank de-
finition.) Severely contorted beds in the Whatcom County
area contain the highest rank coal.
Several underground and surface mining operations are active
in the Washington coal seams. The most notable of these is
the Centralia coal mine which surface-mines coal in the
Centralia-Chehalis Field ranges from 26 to 40 feet. Under-
ground seams run considerably thinner.
'pp. 536, 536,
37
-------
10 0 10 20 30 «0 MILES
3867-14
nlhroclti coal
Bituminous coal
Subbitumlnoul cool
UgnlM
Coal Areas
Whatcom County
Skagit County
Centralia-Chehalis
Morton
Issaquah-Grand Ridge Eastern Lewis County
Green River
WiIkeson-Carbonado
Fairfax-Ashford
Kelso-Castle Rock
Roslyn
Taneum-Manastash
Figure 11. Coalfields of Washington1
38
-------
Wyoming (51,228 MMT Demonstrated ReservesJ
Coal bearing areas underly over 40,000 square miles or
approximately l\l% of the state. Over 136 billion tons of
remaining coal resources to a depth of 3000 feet are thought
to exist in a mapped and explored category.11 Ten major
regions—Powder River, Green River, Hams Pork, Hanna,
Wind River, Bighorn, Rock Creek, Jackson Hole, Black Hills,
and Goshen Hole—contain the 42 coalfields identified in
Figure 12.
Coal ranks from lignite to high-volatile A bituminous.
(Refer to Table 26 for coal rank definition.) Lignite is
found only in the northeastern part of the Powder River
Basin. Bituminous coal is restricted to the Black Hills
Region and portions of the Hanna Field, Green River Region,
Hams Fork Region and Bighorn Basin. High-volatile B and A
bituminous coal is reported only in the Hams Fork Region.1
Subbituminous coal is found in nearly all of the major regions,
Wyoming mining trends lean heavily toward surface mining
although some underground operations are active. Coal seams
can exceed 100 feet in thickness in some areas.
3.1.2 Principal Coalfield Resources
Table 6 gives a partial listing of the rank, age and for-
mation of major coalfields in six of the ten states included
in this study. The resources figures are derived from a
11Glass, G. B. Wyoming. Coal Age. ?8(5):193» Mid-April 1973
1p. 566.
39
-------
(1) Jackson Hole (15)
(2) Grass Creek (16)
(3) Meeteetse (17)
(4) Oregon Basin (18)
(5) Silvertip (19)
(6) Garland (20)
(7) Basin (21)
(8) Southeastern (22)
(9) Bego (23)
(10) Sheridan (24)
(11) Spotted Horse (25)
(12) Little Powder (26)
River (27)
(13) Powder River (28)
(14) Barber
Buffalo (29)
Sussex (30)
Pumpkin Buttes (31)
Gillette (32)
Dry Cheyenne (33)
Glenrock (34)
Lost Spring (35)
Aladdin (36)
Sundance (37)
Skull Creek (38)
Cambria (39)
Goshen Hole (40)
Rock Creek (4l)
Hanna (42)
FROM IERRYHILL,19SO
Kindt Basin
Great Divide Basin
Little Snake River
Rock Springs
Labarge Ridge
Evanston
Kemmerer
Greys River
McDougal
Muddy Creek
Pilot Butte
Hudson
Alkali Butte
Powder River
Figure 12. Coalfields of Wyoming1
565-
-------
Table 6. PRINCIPAL COALFIELDS OP THE WESTERN STATES3
State
Arizona
Colorado "
Montana
New Mexico
Utah
Wyoming
Field
Black Mesa
Denver Region
Raton Mesa
North Park and
Middle Park
San Juan Region
Green River
Region
Ulntah Region
Bull Mountain
Bighorn Basin
Great Falls
Lewlston
Bearpaw Mtns.
Blackfeet-
Valler
Electric
Livingston
Trail Creek
Lombard
Lignite Area
Sub Bit Area
San Juan Basin
Kaiparowits
Kanab Kolob
Wasatch Plateau
Book Cliffs and
Northern
Wasatch
Kemmerer
Rock Springs
Hanna
Wind River
Basin
Bighorn Basin
Powder River
Basin
County
Navajo, Apache,
Cocnnlno
Weld, Morgan,
Boulder, Adams,
Arapahoe, Elbert
Douglas, El Paso
Huerfano, Las
Anlmas
Jackson, Grand
Dolores ,
Montozuma,
La Plata,
Archuleta
Mo f fat, Routt
Rio Blanco,
Garfleld, Mesa,
Delta, Pltkln,
Qunnison
Yellowstone,
Musselshell
Carbon
Cascade, Judith
Basin
Judith Basin,
Fergus
Hill, Liberty,
Formation
Dakota and Mesa
Verde (Wepo)
Laramle, Dawson
Arkose
Vermejo, Raton
Coalmont
Mesa Verde
(Menefee, Fruit-
land) Dakota
Mesa Verde
(Use, Williams
Fork) Lance,
Fort Union
Mesa Verde
(Use, Williams
Fork)
Fort Union
Fort Union
Morrison
Morrison
Eagle SS, Judith
Chouteau, Fergus,
Blalne, Toole
Glacier, Pondera.St. Mary River,
Teton
Park
Park, Gallatln
Oallatin,
Broadwater
San Juan,
McKlnley
Kane, Garfleld
Kane, Oarfleld,
Iron, Washing-
ton
Sanpete, Sevler,
Emery, Carbon
Carbon, Emery
Lincoln, Ulnta
Sweetwater
Carbon
Fremont , Natrona
Park, Hot
Springs, Big
Horn, Washakle
Sheridan,
Johnson ,
Natrona,
Converse,
Niobrara, Weston
Crook, Campbell
TWO Medicine
Montana Group
Montana Group
Montana Group
Fort Union
Fort Union
Mesa Verde
(Fruit land,
Menefee, Dilco)
Straight Cliffs
Tropic, Straight
Cliffs
Mesa Verde
(Blackhawk)
Mesa Verde
(Blackhawk)
Adavllle,
Frontier
Mesa Verde
(Rock Springs,
Almond) Lance,
Fort Union,
Wasatch
Mesa Verde,
Medicine Bow,
Ferris, Hanna
Mesa Verde, Fort
Union, Meeteetse
Mesa Verde,
Meeteetse, Lance
Fort Union
Lance, Fort
Union, Wasatch
Age
Cretaceous
Iretaceous
Paleocene
Iretaceous
'aleocene
'aleocene
Jretaceous
Cretaceous
Paleocene
Cretaceous
Paleocene
Paleocene
Jurassic
Jurassic
Paleocene
Paleocene
Cretaceous
Cretaceous
Cretaceous
Cretaceous
Cretaceous
Cretaceous
Cretaceous
Paleocene
Cretaceous
Paleocene
Cretaceous
Paleocene
Cretaceous
.Paleocene
Cretaceous
Paleocene
Eocene
Estimated Resources
Rank (million ton)
Sub-bltumlnous
Sub-bltumlnous
B It C to Lignite
Jituminous
High Volatile A-B
Sub-bituminous
Jituminous
High Volatile C
to Sub-bituminous
Anthracite to
Sub-bituminous
Sub-bituminous
Sub-bituminous
High Volatile B
Bituminous
3ituminous
Bituminous
High Volatile A
High Volatile A
High Volatile A
Lignite
Sub-bituminous
Sub-bituminous
High Volatile C
Bituminous to
Sub-bituminous
High Volatile A-C
High Volatile A-C
High Volatile A
Sub-bituminous to
High Volatile C
High Volatile C to
Sub-bituminous
High Volatile C to
Bituminous
Sub-bituminous to
Lignite
1,000
5,260.08
12,671.71
3,735.1.)
9,760.19
23,607.5t
211,001.13
1,000
1,217
1,200
215,000a
(total)
11,500
1,355
1,000
3,000
7,500
2,880
2,661
3,917
(total)
150
(total)
9,500
(total)
aOf this figure 5,112 million tons is covered by less than 120 feet of overburden and Is considered
strlppable.
-------
variety of sources and can only be taken at face value since
it is unclear what basis was used to compute the tonnages.
Additionally, the data do not reflect new field discoveries
new resource estimates, or coal production depletion. A
more comprehensive listing of field resources is presented
in Appendix A.
The coal reserve and resource data presented in Section 3.1
and in Appendix A were primarily extracted from open file
government documents and related coal literature. The
attempts to catalog accurate, reliable tonnage estimates of
coal reserve data have resulted in many discrepancies
between various authors. This is especially true for ton-
nage estimates for individual coalfields (Appendix A).
The reasons for this problem are the highly proprietary
nature of reserve estimates measured individually, and the
lack of a consistent basis from coalfield to coalfield.
The data are an indication of the present situation and
represent the best information available through the open
literature.
It is proposed that more exhaustive, reliable and useful
estimates of coal reserves be made available on open file.
This can be accomplished without violating proprietary de-
posit information by categorizing all coal deposit data in
the "measured and indicated" category as defined by the
Bureau of Mines. Since most proprietary coal reserve esti-
mates are made by geological survey organizations, it would
be their task to "non-proprietize" the data. More of the
already existing information on specific "measured" reserves
may then become available when combined with "indicated"
reserve estimates.
-------
3.2 MINING TECHNOLOGY
Coal mining in the West is mechanized to a high degree due
to the severe shortage of skilled coal miners. Modern
western coal mining operations are very large and efficient
with high production per man per shift as seen in Table 7-
Figures 13 and 14 show actual and projected output per man
per day for the total U.S. to 1985. The 1969 Federal Coal
Mine Health and Safety Act is seen to affect output but with
a diminished effect after ten years.
Only large operators with definite market commitments can
afford the capital cost and expenditures involved in equip-
ping and operating an efficient western coal mine.3 A
description of individual coalfield characteristics such as
seam thickness, topography and related items may be found
in Appendix B. These characteristics dictate the method
of mining and affect productivity.
3.2.1 Methods of Coal Mining
The following is a review of literature on the present
status of coal mining methods in the western United States.
Typical mining operations in the West use either underground
or surface mining methods. Horizontal auger mining is less
common but is gaining acceptance due to the large amounts of
coal left in strip mine high walls. A description of each
method of mining follows.
3
p. 10.
-------
Table 7- AVERAGE PRODUCTION OF BITUMINOUS COAL
AND LIGNITE IN THE WEST PER MAN SHIFT, I960 and 19663
State
Colorado
Montana
New Mexico
North Dakota
Utah
Wyoming
Total Tons
Average Production rat<
Surface
or
Underground
Underground
Surface
Surface
Surface
Underground
Surface
a
I960 1966
Tons Tons
Total
3,607,286
313,423
294,762
2,524,955
1,954,693
2,024,196
13,719,315
-
Prod/man-
shift
9-34
13.01
7.27
36.93
10.71
29.33
-
17.90
Total
5,222,372
419,180
2,755,296
3,542,839
4,635,330
3,670,137
20,245,154
-
Prod/man-
shift
15.68
23.37
43. .46
56.81
15.93
49.07
_
32.93
10.
-------
30
25
20
ACTUAL
PROJECTED
15
O
D
0
O
cc
Q- 10
1950
1965
1960
1965 1970
YEAR
1975
1980 1985
Figure 13. Output tonnage per man per shift at all
underground bituminous coal mines12
12Reichl, E. H. U.S. Energy Outlook - Coal Availability
Chairman Coal Task Group. National Petroleum Council.
1973- P. 36.
-------
45
40
35
ACTUAL
PROJECTED
CO
<
30
CJ
Q
O
cc
a.
25
20
15
1950
1955
1960
1965 1970
YEAR
1975
1980
1985
Figure 14. Output tonnage per man per shift at all
surface bituminous coal mines12
12
P. 37-
-------
3.2.1.1 Underground mining methods -
Underground or deep mining is used in the West to extract
the higher quality bituminous coals such as those used in
coke manufacturing. These bring a higher price than the
lower quality, strippable subbituminous coals. Underground
mining in the West is confined primarily to Colorado and
Utah, the major sources of these types of coals.
Full-scale mechanization of underground mining due to
improved technology has increased the output of these mines.
However, mechanization has not decreased the complexity of
the overall underground operation. All systems of western
underground mining are executed in two distinct phases:
the development phase and the production phase.3 The
development phase is used to gain access to the deep coal
seam. Depending on geological and economic criteria, access
may be by vertical shafts, inclined shafts, or slope and
drift entries. Figure 15 shows these entry types. Panels
of coal are exposed for mining by tunneling around the
perimeter of a planned coal block. Other entries are
established for ventilation in multiples of 2 to 7 depending
on the design.3
The production phase is executed in one of two ways: the
traditional room-and-pillar system or the newer longwall
system which is becoming widely used. The typical room-and-
pillar approach consists of rapidly moving the coal away
from the working face in a series of operations. Undercutting
3pp. 11, 11.
-------
Tipple
Fan
Tim*
Figure 15. Three types of entrances to
iderground mines—shaft, slope, and drift13
7^ ^f;- ' Ragle's Handbook of Industrial Chemistry.
th Edition New York, Van Nostrand Reinhold Company,
' 3 ; C°Pyrlght 197^ by Litton Educational
o nC> RePrlnted by courtesy of Van Nostrand
Heinhold Company.
-------
the coal panel, drilling and blasting, and loading are basic
divisions of the operations. High capacity conveyors trans-
port the load from the coal face to exterior haulage equip-
ment. Figure 16 shows the basic operations of this
conventional mining.
Adoption of novel ideas on room-and-pillar mining have
recently eliminated coal face undercutting and blasting.
The advent of the continuous mining machine which mechanically
rips or bores out the coal and loads it in a single con-
tinuous operation has done much to increase the safety and
productivity of underground mines.3 Figure 17 depicts a
continuous mining machine in operation. Both continuous
mining and conventional mining may occur in the same coal
mine. Figure 18 shows the layout of an idealized conven-
tional underground mining cycle. This layout makes the most
efficient use of the underground coal conveyors as seen by
the staggered coal loading points in the cycle. A typical
example of a mine utilizing this cycle is the Plateau Mine
of the Plateau Mining Company.1»14 The mine is located near
Price, Utah, in Carbon County and produces steam coal from
the 8-foot thick Hiawatha seam.
Longwall mining is a system where coal is taken out in a
single continuous operation with the coal face advancing in
an unbroken line or wall. No supporting pillars of coal
are left after the operation since the roof is allowed to fall
and settle behind the props as the mining advances.3 The
3pp. 12, 13-
1p. 724.
lt+Hileman, D. H., B. A. Collins, and S. R. Wilson. Coal
Production From the Uinta Region, Colorado and Utah. Bureau
of Mines Information Circular. 8497- 1970. p. 8.
-------
UNDERCUTTING MACHINE
BLASTING
SHUTTLE CAR
LOADER
COAL PILE
Figure 16. Basic steps in conventional mining13
13
P. 31.
-------
Figure 17. Continuous mining machine13
13P. 32.
51
-------
READY TO LOAD
LOADING MACHINE
CUTTING MACHINE
DRILLING MACHINE
Figure 18. Idealized panel development showing method
of working places in room-and-pillar conventional
12.
52
-------
longwall face may be over 300 feet in length depending on
seam conditions. Figure 19 gives an overhead view of a
typical longwall layout.
The advancement of longwall mining in the United States was
aided by the development of "yielding props" or roof supports.
The supports yield slightly to the increasing roof pressure
that results from mining into the coal face. The supports
are usually actuated hydraulically, and they enable the roof
to fall in a controlled manner after a specified width of
coal face has been mined. They are also self-advancing
which reduces labor and the hazards involved in setup.
Coal is sheared off the supported longwall face by a power-
ful drum shearer that directs the cut coal to a steel plow.
The plow deflects the bulk of the material to conveyors.
The coal shearing equipment traverses the length of the
longwall face. After each pass the roof supports are
automatically advanced and another mining cycle begins.
Figure 20 shows a longwall mining machine operating on the
coal face. Longwall mining finds application in under-
ground mining areas that have poor top support and highly
pitching seams, where room-and-pillar mining is difficult.15
It is also being used as the sole mining method in some
mines because of its higher productivity over room-and-pillar
methods which leave support columns unmined. If properly
operated, the longwall mine is quite safe due to the con-
trolled collapse of mined out areas. Longwall mining is not
applicable to discontinuous coal seams.
15Jackson, D., Jr. Longwall Mining: Western Style.
Coal Age. 76:72, April 1971.
-------
Figure 19. Plan view of typical longwall layout3
3P. 15.
-------
Figure 20. Longwall mining machine13
i 3
P. 32.
55
-------
A typical example of longwall mining activity in the West is
the Sunnyside No. 3 mine of the Kaiser Steel Corporation in
Sunnyside, Utah.15,16 The 5^-inch thick Upper Sunnyside seam
is producing coal of metallurgical coke grade. The Kaiser
development in longwall mining, which was the first success-
ful operation in the West (1961), came initially as a
necessity. Room-and-pillar mining had previously been used
in this mine but had to be stopped due to weak roof structure.
Longwall mining allowed the time to stay open, provided for
increased savings in roof materials, while ensuring positive
roof control and improved overall productivity.
3-2.1.2 Strip mining methods
There are two basic methods of surface mining practiced in
the United States: contour mining and area mining. Both
types can be used only if the overburden thickness is less
than approximately 200 feet. Draglines are prime movers of
overburden and they are technically limited to this maximum
excavating depth.17
Contour mining finds application in hilly terrain where
topography governs pit design.14 Though used in the East,
this method is not widely practiced in the West because of
the vast coal reserves located in its flat or gently rolling
15p. 80.
16Woodruff, S. D. Methods of Working Coal and Metal Mines
Vol. 3. London, Pergamon Press. 1966. p. 239.
17Stefanko, R., R. V. Ramani, and M. R. Perko. An Analysis
of Strip Mining Methods and Equipment Selection. Office
of Coal Research. Report No. 6l. May 1973. p. 77.
1£fp. 29.
56
-------
topography. It is also a more difficult and expensive
operation than area mining. Usually the terrain is quite
rough, and since the coal beds are nearly flat, only a few
cuts can be made before the maximum economic stripping ratio
is reached.14 The stripping ratio is defined as the amount
of overburden removed per ton of coal produced (cubic yards
of overburden/ton coal).16 This quantity increases as coal
is stripped from a hillside coal region, and it soon be-
comes uneconomical to contour mine coal in that area due to
the excessive amounts of overburden to be removed. In light
of the foregoing, contour mining will probably not be con-
sidered as a viable means of mining western coal.
Area mining is the major strip mining method used on western
coal lands. Simply stated, area mining involves the develop-
ment of large flat open pits in a series of long narrow
strips (usually 100 feet wide by a mile or more in length). ll+
The objective is to expose, recover, and haul away the coal
in as economical a fashion as possible, which usually means
that the overburden should be moved only once.
Figure 21 shows two views of a developed strip mine typical
of those found in east.ern Montana. In this case a dragline
initiates the mining cycle by opening a 100-foot wide pit to
expose the 25-foot thick Rosebud coal seam for a length of
one mile.17 Overburden is of an incompetent nature and
blasting is not required to remove it. The coal is drilled
and the boreholes loaded with an ammonium nitrate-fuel oil
14PP. 30, 30.
16p. 39*1.
17p. 49.
57
-------
SURFACE V DRAG
SHIGHWALI/
EXPOSED
ROSEBUD
SEAM
PLAN VIEW
8' McCAY
SEAM
SECTION VIEW
Figure 21. Initial pit dimensions for
dragline exposing the Upper Rosebud Coal Seam17
17p. 50.
58
-------
(ANFO) mixture for blasting. Following blasting, a loading
shovel removes the entire pit width by loading into several
100-ton haulage trucks which take the coal to the crusher.
Two bulldozers begin leveling the spoil. Since two coal
seams are present, the dragline again comes into play,
removing the partings to expose the 8-foot thick McCay seam.
The new seam is worked in the same manner, and the dragline
moves into position to open the next pit. All overburden
from each successive pit is placed into spoil banks located
in the previously mined out pit.
The cycle is then repeated to the limit of the mine
boundaries. Bulldozers level the spoil to a rolling contour
in anticipation of new legislation for strip mine reclamation.
The planting of trees and grasses chosen for their ability
to survive the semi-arid conditions is the final step and is
considered a vital part of the strip mine planning.
Area strip mining is largely equipment intensive and fre-
quently the equipment selection guidelines are derived solely
from past experience. The variety of excavating and haulage
equipment is vast. The major parameters that influence
equipment selection are coal production rate, type and depth
of overburden encountered, spoil pile height, thickness of
coal deposit, maintenance, and weather conditions.17 However,
in practice equipment is usually selected for range and
production capabilities and then the pit is designed to suit
the selected equipment.17
17pp. 85-105, 85-105.
59
-------
Two kinds of excavating equipment not mentioned previously
are scrapers and bucket-wheel excavators. Scrapers can be
used instead of high cost draglines for removing overburden
if the overburden is fairly soft and easily broken. Scrapers
are also useful when the coal seam dips at such an angle that
it would not be economical to strip with a dragline.18
Bucket-wheel excavators are expensive, high production rate
machines that may be selected when dragline capacity is in-
adequate. Their maintenance usually is considerably costlier
than that required for draglines. Bucket-wheel excavators
are frequently used in tandem operation with draglines.
Another item of coal handling equipment recently receiving
much attention in the West is the highly mobile rubber-
tired front-end loader. Table 8 summarizes the character-
istics of strip mining equipment, aad Table 9 gives typical
capacities of the equipment.
3.2.1,3 Auger mining methods
Coal augering is normally used to mine the high walls left
by strip mining operations. This mining system bores
horizontal perpendicular holes in the coal face and extracts
the coal by means of a screw attached to the auger bit.16
Conveyors handle the coal thus produced. Figure 22 shows
a dual-bit coal auger in operation. Augering of coal can
add significantly to the amount of recoverable coal reserve
18Haley, W. A., J. D. Button, and J. P. Tuf f ey . An Economic
Evaluation of Wheel Tractor Scrapers. Coal Age. 77:97
June 1972.
16pp
60
-------
Table 8. CHARACTERISTICS OP
EXCAVATING AND HAULAGE EQUIPMENT3
EXCAVATORS
SHOVELS
1. Can give high production.
2. Can handle all types of material including large blocky
material.
3. Are limited to fairly rigid operating conditions.
4. Require supporting equipment for waste disposal except
in some strip mining.
DRAGLINES
1. Have the ability to dig well above and below grade.
2. Can function under less rigid operating conditions
than shovels,
3. Are only 75 to 80$ as efficient in production as a
shovel of comparable size due to less precise motions.
4. May or may not require supporting waste haulage
equipment.
5. Are normally used for handling unconsolidated and
softer materials, but larger units can handle blasted
rock.
SCRAPERS
1. Have excellent mobility.
2. Are limited to fairly soft and easily broken material
for good production, although they can handle broken
material up to about 21 in. in size.
3. Usually require pushers to assist in loading.
4. Usually are operated without supporting disposal
equipment where the distance to the dump area does
not exceed one mile,
BUCKET-WHEEL EXCAVATORS
1. Must be operated under very rigidly engineered conditions.
2. Have very high capital cost.
3. Are limited to fairly easy digging.
4. Are capable of high production rates.
5. Require auxiliary disposal systems.
3
P 17.
61
-------
Table 8 (continued). CHARACTERISTICS
OP EXCAVATING AND HAULAGE EQUIPMENT3
HAULAGE EQUIPMENT
BULLDOZERS
1. Are commonly limited to a fairly short operating radius
of about 500 feet.
SCRAPERS
1. Require good roads to minimize tire costs.
2. Are fast but are limited economically to an operating
radius of approximately one mile.
TRUCKS
1. Require good roads to minimize tire costs.
2. Can negotiate steep ramps.
3. Are usually limited by economics to an operating radius
of about 2-1/2 miles.
4. Are very mobile.
TRAINS
1. Are high-volume, long-distance, low-unit-cost carriers.
2. Require tracks that closely conform to engineering;
specifications.
3. Have a high initial capital cost.
4. Cannot handle adverse grades much greater than 3%.
5. Can handle coarse, blocky material.
CONVEYORS
1. Are high-volume, long-distance, low-unit-cost carriers
2. Are difficult and costly to move.
3. Have a high initial capital cost.
4. Can handle steep adverse grades (up to about 405?).
5. Require material broken into fairly small pieces for
good belt life.
3P. 17.
62
-------
Table 9. TYPICAL CAPACITIES OF WESTERN
STRIP MINING EQUIPMENT IN 197319
Arizona
Montana
New Mexico
North Dakota
Wyoming
Draglines,
cubic yards
14-36
30-70
10-50
28-32
17-62
Shovels ,
cubic yards
16
16
15-24
?
15-24
Haulage Units,
tons
120
100-120
50-120
40-120
50-120
19Glass, G. B. Recent Surface Mining Development in the
Western States. Geological Survey of Wyoming at Laramie,
(Paper presented at 1974 Coal Convention, American Mining
Congress held in Pittsburgh, Pennsylvania, May 7, 1974,)
p. 4.
63
-------
Figure 22. Dual coal auger16
-------
in a strip mine. A single-bit augering machine was used
to follow up surface mining near Reliance, Wyoming, in 1971
and 1972.20 Augering was discontinued in 1972 because the
mine closed. The auger-mined seams ranged between 4 and 10
feet thick. The augering operation was a success since
12,000 tons of otherwise unrecoverable coal were mined in a
few months. Augering operations are not widely used in the
West, but it is probable that combined strip mining/auger
mining trends will evolve due to both attractive economics
and legislation limiting extensive strip mining.
3.2.2 Methods of Coal Preparation
The washing of coal refers to the process of removing im-
purities prior to coal utilization as a fuel. Current
state-of-the-art washing removes some part of coal ash and
total coal sulfur. The objective of washing steam coal is
to increase the coal's dollar market value by upgrading the
calorific value (ash removal) and/or to lower the pollution
hazard (sulfur removal). Coking coal is often washed to
meet rigid sulfur and ash level restrictions, which, if ex-
ceeded, affect the quality of steel or other metal products.
Current wash practices are limited to physical separation of
the impurities from coal. Methods of washing are divided
into four categories as they apply to coarse and fine
concentration of coal. These are as follows:21
20Glass, G. B. Summary of Coal Mining in Wyoming. Wyoming
Geological Association. (Presented at 25th Field Confer-
ence, Laramie, Wyoming, 1973.) P. 124.
2Leonard, J., and D. R. Mitchell. Coal Preparation. New
York. American Institute of Mining, Metallurgical and
Petroleum Engineers, Inc. 3rd Edition. Seeley W. Mudd
Series, 1968. pp. 9-11, 11-20.
65
-------
Category Coal Size Washed
Dense Medium Separation Coarse, Fine
Hydraulic Separation Coarse, Pine
Froth Flotation Fine
Dry (Air) Concentration Fine
3.2.2.1 Ash removal
Underground mined coals are often washed because continuous
mining machines and other coal recovery equipment cannot
distinguish rock partings and impurities from coal. This
is true especially for thin seams. Washing results in some
loss of coal yield tonnage in the refuse fraction. Certain
strip and auger mined coals must be washed to remove rock
and bony partings from thin, badly faulted, or multiple
seams. Table 10 gives the amounts of Western coal cleaned
in 1972. An estimated grand total of over 10 million tons
of coal is cleaned annually. This amounted to 21% of the
total 1972 production.
Although coal cleaning is not extensively practiced in the
West, it is used locally to clean coking coals and particularly
dirty steam coals. This can upgrade the calorific value in
many instances. In Table 10 it is fairly safe to assume that
the underground coal cleaned was used for coke and the strip
coal was used for steam. Economics generally dictate that
Western steam coal be used "as is" because any increase in
Btu content per pound would be unable to offset the large
transportation costs to midwest markets.
66
-------
Table 10. WESTERN COAL CLEANED MECHANICALLY IN 197222
(Thousand Short Tons)
State
Colorado
Utah
Washington
Arizona
Montana
New Mexico
North Dakota
Wyoming
Total Western
States
Underground Mines
Total
Production
3070
4770*
29
1472
9341
Cleaned
1240
3333
29
713a
5315
Strip Mines
Total
Production
2452
32
2606
35510
40600
Cleaned
-
-
2597
2395a
49923
Auger Mines
Total
-Production
-
-
-
-
Cleaned
-
-
-
-
Total, All Mines
Total
Production
5522
4802
2635
36982
49941
Cleaned
1240
3333
2626
3108a
10307a
stimated
22Anon. Minerals Yearbook 1972. Volume I,
Bureau of Mines, 197*1. PP. 344-3^6, 373-
Metals, Minerals, and Fuels
-------
3.2.2.2 Sulfur removal -
The three forms of sulfur which constitute total coal
sulfur content are pyrltlc (FeS2), sulfate (S0u=)f and
organic (RSH, RSR, RSSR, and thlophenlc).2l Only the
pyrltlc form of sulfur can be removed from coal by current
Physical separation methods. The sulfate and organic forms
are termed "bound" because they are removable only by methods
which can penetrate the coal matrix. Chemical leaching and
solvent refining are two examples of experimental methods
which can remove organic sulfur.
The predominant form of sulfur in western coals is organic
form. Inherently low sulfur content precludes the need for
further sulfur removal in most of these coals. The
assumption that all western coals are inherently low in
sulfur is fallacious in that point-to-point variations can
exist. Some western coals, mainly in parts of Montana and
North Dakota, do not meet 1971 EPA standards of 0.6 Ib
sulfur per million Btu (see Section 5). There is a great
need for a reliable large scale process to remove organic
sulfur from coal.
3.3 COAL PRODUCTION/CONSUMPTION AND PRICES P.O.B. MINE
A total of about 109 western coal mines produced nearly 58
million tons of bituminous, subbituminous and lignite coal
in 1973. Forty-nine of these 109 mines produced over
100,000 tons per year. Table 11 gives a state-by-state
21PP. 1-44 and 1-45.
68
-------
Table 11. TOTAL STATE COAL PRODUCTION, 197322>23
(thousand short tons)
a\
State
Arizona
Colorado
Montana
New Mexico
North Dakotab
Oregon
South Dakota
Utah
Washington
Wyoming
Totals
% Total Western
Coal
% Total U.S.
Number ofc
Strip Mines
2965
2855
9930
8278
7400
0
0
35
3175
12920
47558
82.2
17.3
1
8
6
4
14
0
0
1
2
13
^9
46
2.1
Number ofc
Deep Mines
0
3377
20
1062
0
0
0
5105
35
680
10279
17.8
3.4
0
27
3
1
0
0
0
21
1
5
58
54
2.9
Production
Total
2965
6232
9950
9340
7400
0
0
5140
3210
13600
57837
100.0
10.0
alncludes coking coal production
bLignite
C1972 data
22PP. 345, 346.
23Nielsen, G. F.
Inc. 1974. p,
1974 Keystone Coal Industry Manual.
446.
New York, McGraw-Hill,
-------
breakdown of surface and underground production by method of
mining for 1973. It Is seen that 82% of the western product
came from surface mines, even though there are fewer surface
mines than deep mines. Nearly 58 million tons produced in
the West represent 10* of the 1973 U.S. total. Wyoming
leads in production totals by a substantial margin with 23%
of the total western production. A listing of production by
major mines for 1972 and 1973 may be found In Appendix C.
Production is expected to increase rapidly in the immediate
future. Although stringent strip mining legislation threatens
to shut down all western surface mining activities, it is
not expected to take effect for several years (see Section
3.4.3). Production estimates and projections for the next
several years for five major surface mining states are shown
in Table 12.
Increased production of western low-sulfur coal depends
largely on the ability of mining administrators to obtain
long-term contracts with the industry. The high capital
cost Involved in mining operations must be justified by
long term production and economies of scale.
Table 13 shows a forecast by Mineral Industry Surveys for
1980-1981 western coal annual production. This projection
is for mines on Federally owned lands (35$ of western coal
areas). A western production of 85 million tons is fore-
cast for use by major contract holders as far away as
Louisiana and Illinois. Much of this tonnage, the majority
of which is low sulfur coal, however, can be affected by
legislation pertaining to coal production on Federal lands.
Some discussion of western coal mining legislation is pre-
sented in Section 3.4.3.
70
-------
Table 12. ANNUAL COAL PRODUCTION (1969-1972) WITH ESTIMATES FOR
1973, 1975, 1980, and 198519
Production in Millions of Tons
State
Arizona
Montana
New Mexico0
North Dakota13
Wyoming
Totals
1969
.0
1.0
4.5
4.7
4.6
14.8
1970
0.1
3.4
7.4
5.6
7-2
23-7
1971
1.1
7.1
8.1
6.1
8.1
30.5
1972
1.1
8.2
8.2
6.8
10.9
35-2
1973
2.9
9.9
9.3
7-4
13-6
43.1
1975
10.0
19.8
17.0
11.7
22.9
81.4
1980
13-0
41.0
27.0
19-0
87.0
187-0
1985
13.0+
74.0
27.0+
49.1
140.0
303.0
aForecast by Arizona Bureau of Mines, 1973
bForecast by Northern Great Plains Resource Program (most probable), 1973
°Forecast by New Mexico State Bureau of Mines and Mineral Resources, 1973
•
Forecast by Wyoming Geological Survey, March 1974
19
p. 1.
-------
Table 13. PROJECTED COAL PRODUCTION PROM FEDFRAr
SURFACE COAL MINES FOR STEAM ELECTRIC PLANT FUFTs
FOR 1980-198121*
State
Colorado
Montana
North Dakota
New Mexico
Utah
Wyoming
Grand Total
Major Contracts
Location of Mine Annual Tons Location of Powerplant
Oak Creek
Hayden
Craig
Sub-total
Colstrip
Colstrip
Colstrip
Colstrip
Colstrip
Colstrip
Colstrip
Colstrip
Savage
Decker
Decker
Decker
Sub-total
Beulah
Beulah
Gascoyne
Stanton
Center
Zap
Sub-total
Fruitland
Gallup
Sub-total
Alton
Sub-total
Glen Rock
Hanna
Hanna
Hanna
Hanna
Point Rocks
Kemmerer
Gillette
Gillette
Gillette
Gillette
Gillette
Gillette
Gillette
Gillette
Gillette
Gillette
Sub-total
800,000
1,000,000
600,000
2,400,000
280,000
800,000
1,600,000
920,000
1,200,000
1,200,000
1,500,000
2,200,000
90,000
5,300,000
6,500,000
8,300,000
29,690,000
200,000
160,000
250,000
1,000,000
100,000
500,000
2,510,000
3,600,000
250,000
3,850,000
5,600,000
5,600,000
3,500,000
100,000
1,300,000
1,200,000
4,500,000
3,000,000
250,000
520,000
1,400,000
2,400,000
3,500,000
6,400,000
3,700,000
1,800,000
1,000,000
1,700,000
5,000,000
41,270,000
85,520,000
Denver, Colorado
Hayden, Colorado
Craig, Colorado
Billings, Montana
Minneapolis, Minnesota
Chicago, Illinois
Wisconsin
St. Paul, Minnesota
Colstrip, Montana
Cohaaset, Minnesota
Becker, Minnesota
Sidney, Montana
Chicago, Illinois
St. Clair, Michigan
American Electric Power
(Locations Unknown)
Hoot Lake, Minnesota
Beulah, Mandan, N.D.
Ortonville, South Dakota
Stanton, North Dakota
Center, North Dakota
Stanton, North Dakota
Fruitland, New Mexico
Joseph City, New Mexico
Las Vegas, Nevada
St. George, Utah
Glen Rock, Wyoming
Denver, Colorado
Sioux City, Iowa
Council Bluffs, Iowa
Nebraska
Point of Rocks, Wyoming
Kemmerer, Wyoming
Rapid City, South Dakota
Gillette, Wyoming
Pueblo, Colorado
Avlnger, Texas
Topeka, Kansas
Muskogee, Oklahoma
Western Nebraska
Amarlllo, Texas
Louisiana
Redfleld, Arkansas
Anon. Assessment of the Impact of Air Quality Requirements
on Coal in 1975, 1977, 1980. Bureau of Mines Mineral Industry
Surveys, Division of Fossil Fuels, Mineral Supply. January
Pp. 178-179.
72
-------
The distribution and utilization of western coal are
important from the standpoint of out-of-state marketability.
Table 14 gives the definition of western producing districts
as outlined by the U.S. Bureau of Mines. These districts
are shown in Figure 23. Table 15 shows points of destination
from these western coal producing districts along with
associated tonnage. It is seen that the ultimate destinations
of western coal are primarily in-state and midwestern, with
one exception shipped to New York. Most western coal (70$)
stays in the western regions. Additional information on
utilization by individual user type is found in Appendix D.
An interesting aside is the change in total production in
just one year's time. Roughly 50 million tons were pro-
duced in 1972 while 58 million tons were produced in 1973.23
Colorado and Utah produce the majority of coking coals in
the West. Table 16 shows 1972 annual production figures for
the states having the most high quality coking coal potential.
All of this coal was mined underground. The 1972 data in
Table 16 indicate that coking coal production tonnage is minor
in comparison with steam coal production. Over 90% of the
coal produced in the West was used for steam production in
1972.
A list of the latest actual average yearly surface and under-
ground coal prices (f.o.b. mine) is given in Table 17. Under-
ground coal costs considerably more than surface coal because
of higher costs of mining and usually superior coking and
73
-------
Table 14. DEFINITION OP WESTERN BITUMINOUS
COAL AND LIGNITE PRODUCING DISTRICTS25
DISTRICT 16. - NORTHERN COLORADO
All mines In the following counties In the State-
Adams Douglas Jackson Larimer
Arapahoe Elbert Jefferson Weld
Boulder El Paso
DISTRICT 17. - SOUTHERN COLORADO
Colorado - All mines except those included in District 16
New Mexico - All mines except those included in District 18
DISTRICT 18 - NEW MEXICO
New Mexico - All mines in the following counties-
Grant McKinley Sandoval San Miguel
Lincoln Rio Arriba San Juan Santa Fe
, , Socorro
Arizona - All mines in the State
California - All mines in the State
DISTRICT 19 - WYOMING
Wyoming - All mines in the State
Idaho - All mines in the State
DISTRICT 20 - UTAH - All mines in the State
DISTRICT 21 - NORTH DAKOTA-SOUTH DAKOTA
All mines in North Dakota and South Dakota
DISTRICT 22 - MONTANA - All mines in the State
DISTRICT 23 - WASHINGTON
Washington - All mines in the State
Oregon - All mines in the State
Alaska - All mines in the State
Anon. Bituminous Coal and Lignite Distribution Calendar
Year 1973. Bureau of Mines Mineral Industry Surveys
Division of Fossil Fuels. April 12, 1974 p 3
-------
LEGEND
DISTRICTS*
2 - Western Pennsylvania 9 - West Kentuc*;
3 - Northern West Virginia 10 - Illinois
5 - Micnigcn 12 - io«a
7 - Southern No I 14 - Arkansas-Dak'
15 - Southwestern
17- Southern Colorado
18 - New Menco
19- Wyoming
20- Utflti
21 North-South Dakota
defined in Ihe Bituminous Cool Act ol 1937
22 - Montana
23- Washington
Figure 23. Coal-producing districts of the United States26
26Mutschler, P. H., R. J. Evans, and G. M. Larwood. Comparative Transportation
Costs of Supplying Low-Sulfur Fuels to Midwestern and Eastern Domestic Energy
Markets. Bureau of Mines Information Circular. 8614 . 1973- P- 5.
-------
wCONSUMPTION BY STATE AND DISTRICT OP ORIGIN"
western coal production basis = 58.890 x 106 tons)a
Point of Destination
State
Illinois
Indiana
Iowa
Michigan
Minnesota
Missouri
Nebraska/
Kansas
New york
Wisconsin
Totals
Arizona/
Nevada
California
Colorado
Montana/Idaho
New Mexico
North/South
Dakota
Utah
Washington/
Oregon
Wyoming
Totals
Consump-
tlonb
6162
1682
1129
119
5251
1072
1251
71
510
17550
1151
2398
6298
1395
7330
5801
3957
3510
6200
11310
Producing
Includes California and
Thousand tons
(MT)
f of
Total0
10.5
2.9
2.1
0.2
Q n
1.8
2.1
0.1
n q
29.8
7.6
1.1
10.7
2.1
12.1
9-8
6-7
6.0
10.5
70.2
District
Idaho
Producing
!6 17 18
T U T U T U T
20 0
15 0 1111
~ ~ 106
13 0 1059
- 196 NA - - 1055
~ —
~ - 180
- 211 NA - - Unit
~ - - - 3706 3683
1171 0
508 NA 1396 2888 - - X391
- 165
~ - - 7330 7325
~ 377
1053 NA - - 33
92
~ - - - - 6200
508 NA 6623 2868 11036 11008 8261
"•9 11.6 18.7 21
District0'8
19
1109
~
101
1059
NA
71
NA
2572 71
- 715
NA
0 321
358
0 2871
0 112
5932
6290 5303
•0 9.
dr,
i - iOtal tonnage shipped or used
U - Tonnage shipped for electric
clncludes utility use
NA » not available
_20 21 22
U T U T
6112
1682
~ ~ ~~
119
1382 NA 3766
0
30
0 1382 NA 11739
— • - —
630
~ —
0 - 909
5121 5023
NA -
0 3276
630 5121 5023 1185
1 11.6 27.
U
6112
1680
—
NA
NA
_
NA
7822
~
—
889
I
_
3216
1135
by corresponding state (MT)
utility use only (MT)
"pp. 1-38.
-------
Table 16. COKING COAL PRODUCED IN THE WESTERN STATES WITH
MAJOR COKING COAL SEAMS IN 1972*»22
(tons)
State
Colorado
Montana
New Mexico
Utah
Washington
County
Gunnison
Las Animas
Pitkin
Mo f fat
Total
Cascade
Gallatin
Park
Total
Colfax
Sante Pe
Socorro
Total
Carbon
Emery
Total
King
Kittitas
Pierce
Skagit
Whatcom
Total
TOTAL COKING COAL
Seams
Somerset B, C and E
Allen
A & B, Upper Basin Bed
—_ .
Belt Creek
No. 2
No. 1
Raton and York
Cook and White
Carthage
Black Diamond, C, Clear
Creek, Kenilworth,
Sunny side
Sunny side
Snoqualmie Nos . 3, 4 & 5
Roslyn Nos. 5 & 6
Nos. 1, 2, 3, 4, 5 & 7
(Fairfax-Montezuma area);
Nos. 1, 2, 3, 4, 4-1/2, 5
6 & 7 (Melmont); Nos. 2,
6, 7, 8, 13, 14, 16 & 21
(Wilkeson-Carbonado Carbo
River field)
No. 1 or Klondike, No. 2
or Middle Vein (Cokedale
area); Nos. 1, 2, 3 & 4
(Hamilton)
Blue Canyon
Production
450,000
616,000
651,000
296,000
2,013,000
0
0
0
0
625,000
0
0
625,000
1,872,000
0
1,872,000
29,000
0
0
0
0
29,000
4,539,000
JPP. 398-402.
22pp. 452-453.
77
-------
Table 17. AVERAGE VALUE OP BITUMINOUS COAL AND LIGNITE, P.O.B. MINE22
00
State
Arizona
Colorado
Montana
Bituminous
Lignite
Total
New Mexico
North Dakota
Lignite
Utah
Washington
Wyoming
U.S. Average
Underground
-
7.80
9.33
9.33
8.05
-
7.37
13.55
6.25
8.87
1971
Strip
wa
3.91
1.79
2.27
1.79
2.61
1.91
8.00
6.52
3.35
5.19
— — — — — _^___^
Auger
_
-
-
-
—
-
-
2.20
6.57
Total
wa
6.34
1.79
2.27
1.82
3.26
1.91
7.37
6.72
3.39
7.07
1972
Underground
8.34
9.74
9.74
10.42
_
8.93
16.40
4.89
9.70
Strip
Wa
4.10
2.00
2.45
2.01 '
2.66
2.02
8.00
6.51
3.69
5.48
Auger
-
-
6.54
W - Withheld to avoid disclosing individual company confidential data
Total
i i
6.45
2.01
2.45
2 0?
1 61
2 .02
8 93
6 6l
3.74
7.66
22P. 386.
-------
heating qualities. Coal prices fluctuate widely due to many
complex interactions, some of which involve coal miner
strikes and market demand fluctuations.
The average prices shown in Table 17 should be considered
conservative. Some local prices have been inflated to two
and three times the average prices. Appendix E gives a
further breakdown of western coal prices by county.
3.4 CONSIDERATIONS AFFECTING THE SELECTION OF WESTERN
COAL MINE SITES
Major factors influencing the decision to mine western coals
for steam generation are reviewed here. It is assumed, as
indicated previously, that adequate reserves of both coal
and water are available, and these are not factors in mine
site selection. Basic economic aspects of coal mining
methods are presented along with ancillary considerations
that contribute to the success or failure of a mining
venture. Current trends have been toward strip mining
because of the thick coal seams near the surface and the
ease of recovering the coal. Due to the vast quantities of
higher quality deep minable steam coal resources, an economic
analysis of underground mining considerations is also pre-
sented along with the strip mining analysis.
The factors that influence western coal development are
broken into three major categories: economic, technological,
and governmental. Table 18 gives economic variables re-
lating to both underground and surface mining. Tables 19
and 20 respectively list technological and governmental
aspects peculiar to underground and surface mining. Strip
and auger mining factors are included under the surface
mining classification.-
79
-------
Table 18. ECONOMIC COST VARIABLES INFLUENCING
GRASS ROOTS WESTERN STEAM COAL MINING DEVELOPMENT
External Factors9-
Internal Factors13
Heating value
Sulfur restrictions
Haul distance
Ash content
Moisture content
Exploration
Construction
Development
Mining equipment
Engineering
Available manpower
Operating supplies
Wages
Union welfare
Coal royalties/leases
Taxes
Insurance
Depreciation
Power/fuel
Post treatment requirements
Reclamation
Coal storage handling
Mining method0
Stripping ratiod
aCost factors that contribute to the success or failure of
the venture as a whole.
Costs maintained in the operation of a mine.
cDeep: conventional, continuous, longwallj
Strip: contour, area, auger/strip.
dStrip mining only,
80
-------
Table 19. TECHNOLOGICAL VARIABLES INFLUENCING
GRASS ROOTS WESTERN STEAM COAL MINING DEVELOPMENT
Underground Mining
Surface Mining
Roof support
Underground geological
structure
Methane evolution
Equipment size, type and
quantity
Coal abrasiveness
Underground water removal
Power availability and
transmission
Available transportation
Coal storage
In-ground coal recovery
percentage
Refuse disposal
Water quality control
Overburden characteristics
Seam thickness
Equipment size, type and
quantity
Weather
Reclamation requirements
Available transportation
Topography and pitch of coal
seams
Slope angle
Pit dimensions
Power availability and
transmission
Coal Storage
Land use after mining
Water quality control
Roads
Refuse disposal
81
-------
Table 20. GOVERNMENTAL LEGISLATION INFLUENCING
GRASS ROOTS WESTERN STEAM COAL MINING DEVELOPMENT
Underground Mining
Strip Mining
Federal Coal Mine Health
and Safety Act of 1969
Federal Antiquities Act
of 1906
Mineral Leasing Act of
1920
State regulations
Federal regulations
State regulations
Federal regulations
EXISTING
Federal Antiquities Act of 1906
Mineral Leasing Act of 1920
State regulations
Federal regulations
PENDING
Energy Supply and Environmental
Coordination Act of 1974
State regulations
Federal regulations
82
-------
3-^.1 Western Coal Mining Economics
As with any large industrial venture, it is the production
economics that ultimately decide success or failure. Under-
ground coal mining costs usually center around labor issues
because of the large number of personnel required. The need
for the evolution of bigger and more efficient stripping
draglines and related coal and earth moving equipment has
made strip mining largely equipment intensive.
Breakdowns of various capital cost percentages typically
involved in the setup of various size western strip mines
and one deep mine are shown in Table 21. Mining via con-
tinuous mining machines was assumed for the deep mine costs.
Mining via conventional dragline and stripping shovel
combinations was assumed for the strip mining cases. No
coal washing or post treatment costs were involved in the
calculations. It is evident from these limited data why
strip mining is economically attractive. For nearly the
same capital investment required for a Utah underground mine
one can develop a Montana or Wyoming strip mine with 2.5
times the production capacity. The large capital cost of
underground development is also eliminated by strip mining.
However, capital investment varies markedly from region to
region for strip mining. The lowest capital investment
appears to be in Montana ($13,879,100) and the highest in
the southwest ($28,656,700) for equal strip mine production
capacity (5 MM tons/year). Table 21 demonstrates that strip
mining is largely equipment intensive as witnessed by the
nearly constant direct cost percentage with essentially
doubled total capital investment. The size and number of
83
-------
nl1' ESTIMATED CAPITAL REQUIREMENTS FOR
SURFACE AND UNDERGROUND WESTERN COAL MINES?^.
(% of base)
Production
capacity (MMt/
yr)
Type mine
Life expectancy
(yr)
Base ($)
Direct (mining
equipment,
buildings,
exploration
Field indirect
construction
Engineering
Overhead/admin-
istrative
Contingency
Interest during
construction
Working capital
Pee
Underground
development
»«~^^—M«^_
a!970 dollars.
Utah
2.0
/
deep
15
13,426,179s
63.6
1.5
1.9
2.0
6.9
1.8
8.5
NA
13.7
— 1 Region -
Arizona | Arizona
Colorado
New Mexico
Utah
— "^— ^— -^^•—
1.0
strip
20
' 7,898,100b
74.6
1.5
1.5
3.9
8.1
2.3
6.3
1.8
NA
1
Colorado
New Mexicc
Utah
1
5.0
strip
20
28,656,700
74.2
1.5
1.5
3.9
8.1
2.3
6.8
1.8
NA
— — — — ^_
Montana
5.0
strip
20
3 13,879,100
73.5
1.5
1.5
3.8
8.0
2.3
7.7
1.8
NA
•^ «•__
. —
Wyoming
5.0
strip
20
3 13,921,100
73.2
1.5
1.5
3.8
8.0
2.2
8.0
1Q
. o
NA
™ HI
1 —
North
Dakota
Montana
•^— — — ^M
1.0
strip
20
5 6,38l,8oob
74.6
1.5
1.5
3.9
2.3
6.2
1.8
NA
i
North
Dakota
Montana
— — — — __
1.0
strip
20
2°.749,700a
74.D
1.5
1.5
3.9
8_
.1
2-3
6.5
1.8
NA
b!969 dollars. NA not aPP"caBle
llfpp. 8-11.
"ssa.
-------
overburden removing draglines in a mining operation have a
major influence on capital costs. The Montana 5.0 million
ton per year model employs only one ($5 x 106) large drag-
line while the southwestern operation used three ($15 x 106).
The main factors contributing to the wide differences in
strip mining capital costs are local topography and degree
of mining difficulty peculiar to a region.
Coal selling prices are primarily influenced by production
costs. Annual production costs for these same hypothetical
mines are shown in Table 22. It is seen that despite the
high cost per ton of underground coal, it appears to be
competitive with strip mined coal on a cost per Btu basis
except for the Montana/Wyoming coals. Wide differences
exist between base production costs per ton for strip mines
of equivalent capacity. These differences are caused by the
complex interaction of the variables listed in Table 18.
Several cost items can serve as examples. The contribution
to the United Mine Workers Welfare Fund is $O.MO/ton for
bituminous and subbituminous coal and $0.20/ton in the lig-
Ite fields of North Dakota/Montana.'27 Many western strip
mine operators escape this cost by employing miners who belong
to either the International Union of Operating Engineers or
to no union at all. Payment of royalties to owners of the
coal other than the coal company varies widely ($0.15 to
$0.28 per ton). Deferred expenses, including reclamation
27pp. 1-6
85
-------
Table 22. ESTIMATED ANNUAL PRODUCTION COSTS
FOR SURFACE AND UNDERGROUND WESTERN COAL MINES 1If»27
(% of base)
Region
ITD.II.:' ion
capa-1'.y (K«t
yr)
Tyre nine
Life expectancy
(yr)
BWlb (as
received)
Eise (t/K>. Btu)
Base ($/tan)
?irect
Labor
Operating
supplies
finer
Ir.llrec-
'Jnlon welfare
Payroll over-
nead
5* of labor,
nalntenance
I supplies
royalty
--^preclat Ion
Deferred ex-
penses (re-
tinae lor. ,
power lines)
Taxes, Insur-
ance
Ir.'.epes* jn *crk-
Ir.g capita;
Utah
2.0
deep
15
12,694
12. 7a
3.23a
21.5
26.6
3.1
12.1
NA
1.7
11.8
11.2
1.9
1.4
Colorado
New Mexlc
Utah
1.0
strip
20
10,600
14. 3b
3.33b
16.5
21.8
5.0
13.2
5.6
5.6
5.S
15-2
6.6
4.6
NA
Arizona
Colorado
New Mexlo
Utah
5.0
strip
20
10,600
11. 3b
2.10b
10.0
27.5
6.7
16.7
3.3
5.8
7.5
12.5
5.8
4.2
NA
Montana
5.0
strip
20
8500
8.2b
1.39b
10.8
24.5
2.2
14.4
3.6
5.8
16.5
13.6
5.0
3.6
NA
Wyoming
5.0
strip
20
8500
9.3b
1.58b
10.8
21.5
1.9
25.3
3.8
5.1
12.0
12.0
4.4
3.2
NA
North
Dakota
Montana
1 . 0
strip
20
7200
16. 5b
2.37b
20.3
17.7
5.9
8.1
7.2
5.1
7.6
16.0
6.8
4.6
NA
North
Dakota
5 A
.0
strip
20
7200
11. 7b
1.68b
10.7
25.6
8.3
11.9
3.6
5li
* M
10.7
13.1
6.0
4.8
NA
.170 dollars.
'-'}•'.') JclJars.
;IA r.ot available
27[.p. 69-116.
86
-------
and power line setup, vary because some states have strict
reclamation laws and because power line setup costs are
largely dependent on line distance and local wage rates.
The cost to level spoil banks and replant can amount to as
much as $0.15 per ton. More stringent reclamation regula-
tions can force this figure as high as $1.00 per ton of
mined coal.28
Mining coal reserves with thick seams is of utmost impor-
tance to the economic success of western surface mines. The
large transportation distances and associated cost must be
offset at the mine by low overburden to coal ratios. In the
five major states where surface coal mining predominates
(Arizona, Montana, New Mexico, North Dakota, and Wyoming)
the overburden is relatively thin. No more than 200 feet of
rock and soil overlie the majority of strippable reserves
in these states. As of 1973 most current mining removes
only 30 to 80 feet of overburden. The thickness of coal
seams, some of which are over 100 feet, lowers the over-
burden to coal ratio substantially in comparison with
eastern coals. Overburden to coal ratios in the west
(stripping ratio) are frequently less than 1:1 and seldom
exceed 7:1.
Table 23 shows typical thicknesses of coal seams currently
surface mined in the West.
28McLean, J. G., Chariman. U.S. Energy Outlook - A Report
of the National Petroleum Council's Committee on U.S.
Energy OUtlook. National Petroleum Council. December
1972. p. 145.
87
-------
Table 23. SURFACE COAL SEAM THICKNESS20
(feet)
Wyoming
Montana
North Dakota
New Mexico
Arizona
Maximum
118
60
27
15
30
Minimum
6
5
5
14
U
Average
70
25
16
11
10
20
P. 3.
Taxes previously have been an insignificant part of the coal
production cost, but this is changing. Two states in partic-
ular (Montana and Wyoming) are imposing strict taxes on coal
to provide revenue for reclamation and environmental studies.
The January 9, 1973 Montana legislative session has had a
significant effect on the outlook of coal development. The
1973 session passed the Mining License Tax Act which increased
the 8
-------
The Resources Indemnity Trust Fund Tax is a tax on minerals
extracted to provide a fund for reclaiming land where the
operator does not fulfill his obligations. The tax is 1/2
of 1% of sales price. Along with the existing property
taxes and Net Proceeds of Mines Tax (excise tax on assessed
value of production) the total taxes paid in Montana on coal
ranges from 2?
-------
the skilled manpower shortage in the West is certain to
adversely affect the smooth growth of underground mines.
Direct labor costs for both types of mining methods are
deflated because they do not reflect substantial wage in-
creases resulting chiefly from the United Mine Workers of
America Wage Contracts of 1971 and 1974. The 1971 contract
provided for labor cost increases of 39% for strip and deep
mine workers over a 3-year period.31 Additionally, the 23
day strike by coal mines in late 197^ will have a detrimental
effect on future mine development for mines employing UMWA
workers. The total increase in labor costs for the 1974
three year contract has been calculated to be 64.6/5 over
those of the 1971 contract.32 The employment of workers
belonging to less powerful unions or no union at all is ex-
pected to increase in the future to defray these costs. The
Federal Coal Mine Health and Safety Act of 1969 has de-
creased the level of productivity of deep coal mines. This
forces coal mine labor reserves to increase in order to
maintain productivity. However, shortages of skilled man-
power defeats labor increases. The majority of underground
mines in the West mine high priced metallurgical coking coal
rather than steam coal. It is unlikely that future deep
mines will supply a large portion of coal unless environmental
and reclamation strip mining regulations significantly shift
economics in their favor, or until the underground techniques
such as longwall mining, that can increase production per
man-shift are accepted.
31McClung, J. D., and K. K. Humphreys. Is the Energy Crisis
Real? American Association of Cost Engineers Bulletin.
15(3):77, June 1973.
32Anon. New Labor Contract Provides Wages, Safety, Pension
Improvements. Coal Age. 80:57-59, January 1975.
90
-------
3.4.2 Western Coal Mining Technology Forecast
Conventional room-and-pillar and continuous underground
mining operations generally leave up to 50$ of the coal
mine reserve in place in the form of pillars and supports.28
Strip mining by conventional techniques recovers 90% or
more of the original in-place coal reserve.28 Longwall
underground mining technology improves the recovery factor
and productivity substantially (90$) but is largely untested
in the West and cannot be used in certain underground rock
structures. The fact that only approximately 10% of the
total U.S. coal resources lie within 150 feet of the surface
(maximum economic and practical stripping depth) precludes
strip mining from a major role in the ultimate recovery of
American coal.33 Long-range planning thus points to the
reemergence of underground mining methods. Longwall
stripping methods for surface mining are being investigated
by EPA. This promising mining method would minimize surface
disturbance (see Section 5).
The present trends indicate the continuance of larger and
more efficient strip operations. The main limiters of this
trend are governmental policies, public sentiment, manpower,
and equipment availability.28 Stripping operations with
built-in reclamation programs are necessary if current strip
mining growth is to continue. The thick seams of coal (some
can average over 100 feet) counter the current reclamation
technology. Grading the mined out areas back to original
contours requires that fill dirt be trucked in from other
sources.
28pp. 140, 140, 27.
33Nephew, E. A. The Challenge and Promise of Coal.
Technology Review. 76(2):27, December 1973.
91
-------
3.4.3 Western Coal Mining Legislation
3.^.3.1 Existing legislation - surface mining -
Federal and state provisions regulating surface coal mining
are in continual flux. Federal and state regulations are
presented in Appendix F. These regulations were in effect
as of 1972 and as such do not represent the latest thinking
in this area. Nearly 65% of the western coal lands are
regulated by specific state laws and/or Indian agreements.
The remaining 35% are under the less specific Federal regu-
lations.34 As of 1971 those western states with no state
strip mining regulations per se were Arizona, New Mexico,
Oregon, South Dakota, and Utah.
Existing federal regulations provide for reclamation plans
to be filed with the Mining Supervisor showing methods and
timing of grading and backfilling areas affected by the
mining operation. The reclamation plan also shows the method
of preparing the soil prior to replanting. In lieu of
execution of the plan, the $2000 bond paid by the operator
is forfeited, and the lease is cancelled. State laws are
similar in scope. In certain instances, both state and
federal regulations appear unclear with reference to grading
to original contours and successful revegetation in the arid
West. Most state laws governing surface mining and rehabillta.
tion in the West do not provide for adequate planning, moni-
toring, enforcement and financing of rehabilitation.35
31*Anon. The Coal Industry's Controversial Move West.
Business Week. pp. 134-138, 138. May 11, 1974.
35Box, T. W. Land Rehabilitation: Prompt Passage of
Federal Reclamation Law Recommended by Ford Foundation
Study. Coal Age. 79:116, May 1974.
92
-------
The Federal Antiquities Act of 1906 requires that the his-
torical nature of lands be explored before mineral deposits
are excavated. This act applies to both surface and under-
ground mining. The West is rich in archaeological artifacts
and the coal operator must partially or totally finance the
exploration and artifact recovery operations.
Water allocation laws are also strict in most western states
due to potential shortages in the arid West. The requirements
of water for mining are presented in Section 3^.5. In some
areas the coal seams themselves form part of the aquifers.34
Montana, concerned that its farmers will not have enough
irrigation water, has declared a 3-year moratorium on any
new commitment of water from rivers in eastern Montana.34
4.3.2 Existing legislation - underground mining -
The Federal Coal Mining Health and Safety Act of 1969 has
been the major obstacle in the development and production of
deep mines to date. The major items included in this act
are summarized briefly as follows:36
1. Lower respirable dust levels
2. Lower noise levels
3. Better roof supports
l\. Increased ventilation
5. Monitoring of methane emissions
3«*pp. 138, 138.
36qist Congress, The Federal Coal Mining Health and Safety
III. Public Law 91-173, Sec 2917, (1969) PP. 1-60.
93
-------
6. Improved rock dusting
7. Safer electrical equipment
8. Fire protection
9. Detailed escape routes
10. Blasting limitations
11. Black lung benefits for afflicted miners
3.4.3.3 Recent coal lease legislation -
Under the Mineral Leasing Act of 1920 coal prospecting and
mining are allowed on public land on a lease basis with min-
imum annual rentals (25
-------
example, has over 25 land-use bills pending. Both the U.S.
Senate and the House of Representatives are actively engaged
in strip mining legislation. A senate bill passed in the
fall of 1973 would require strip miners to return the land
they dig up to roughly its original condition.38 The high
cost of reclamation may well significantly alter the way the
U.S. exploits its energy resources. A house bill similar to
the senate bill, passed in late July of 197^ (H.R. 11500),
also bars strip mining in the arid and semi-arid alluvial
valleys of the West, and it forces mining companies to get
permission from ranchers before mining federally leased coal
from under their land.38*39
Montana has taken the lead in passing severe environmental
legislation. The 1973 Montana Strip Mining and Reclamation
Act provides for the control of prospecting and strip mining.
It sets forth stricter provisions for permit requirements,
reclamation plan requirements, methods of operation, penalties
and other controls.29 The 1974 Montana Strip Mine Siting Act
allows the state to approve or disapprove the plans for new
surface mining operations prior to any development and large-
scale investments.29 The 1974 Coal Conservation Act would
require that higher royalties be paid if only the uppermost
seams are mined. The incentive for coal operators in Montana
would be to mine all coal seams, thus preventing restripping
of an area.29 A 3-year water moratorium has been imposed on
large volume water use applications in the Yellowstone
River drainage basin in Montana. The suspension will provide
time to study future water usage.29
38Anon. Going Underground. Newsweek, August 5, 197M, pp. 53-54
39Anon Hosmer Calls Strip-Mining Bill 'Congressional Embargo.'
Energy Digest. 4(11):235, July 15, 1974.
29. 86-88.
95
-------
3.4.3-5 Recent and pending legislation - underground mining -
Following closely behind pending legislation on strip mining
is legislation aimed at cleaning up underground mining oper-
ations. Specific bills are certain to be enacted by state
legislatures on such topics as coal refuse fires and gob pile
disposal. Acid mine drainage is not expected to be of major
concern legislatively because of western coal's inherently
low inorganic sulfur content.
3.4.4 Evaluation of Western Coal Mining Development Factors
The primary factors inhibiting the development of new western
coal mines are:
a. Legislative uncertainties concerning a ban of all
western strip mining
b. High costs of reclamation to original topography
c. Strip and deep mining new equipment availability
d. Transportation uncertainty and long haul economics
e. Skilled manpower shortage and wage changes
f. Lack of new mining technology emphasis (e.g.
longwall mining, co-current reclamation/strip
mining)
g. High capital investment which excludes the small
mine operator.
Mine development hinges on the above" factors as well as on
establishing relationships with utility companies that are
in dire need of low sulfur coal now (Section S-S).40 Quoting
40Goldston, E. Economic Aspects in Developing Coal in the
Rocky Mountains. Coal Age. 77:86, March 1972.
96
-------
from Eli Goldston, Chairman of the Board, Rocky Mountain
Associated Coal Corporation (1972): "Recover coal from
shallow surface mines first, then move on to the deeper
surface mining and ultimately to the deep mining because
the vast percentage of the total reserves are deep mining
reserves.l|lt °
3.4.5 Water Requirements and Availability
Western coal mining operations require water for the
following applications:
a. Land revegetation
b. Pipeline slurry transportation
c. Dust control on haul roads and in mines (underground)
d. Coal cleaning operations
e. Potable supply
Water is scarce in most of the ten states included in this
study. Water usage in mining operations is quantified in a
general sense here, and areas of severe water deficiency are
defined. Water appropriation and allocation is very complex
in the West. New industrial ventures such as coal mining
experience difficulty in obtaining water rights. While the
above water needs are admittedly low in comparison to mine-
mouth power plants and coal gasification requirements, it is
felt that water acquisition is a vital factor to consider
in determining future utilization and mining of the western
coal deposits.
"°p. 86.
97
-------
The success of land revegetation depends primarily on the
availability of water in the arid and semi-arid West and on
soil and areal characteristics that permit moisture retention
and promote growth. Rainfall is the most reliable indicator
of successful probability of growth although irrigation can
augment revegetation. Annual mean precipitation in the West
is low ranging from 4 inches or less in some of the hot deserts
to 20 inches or more in the higher mountains.35 Droughts
are common. Precipitation may come as high intensity, short
duration storms or as snowfall. Those areas receiving less
than 10 inches of annual rainfall are generally considered to
require major, sustained input of water, fertilizer and
management.35 Areas with high evapo-transpiration rates
(i.e., inability of soil to retain moisture combined with
water loss from plants) are classified similarly. The figure
of 10 inches of annual rainfall is not a hard and fast rule
since many other variables are involved in successful plant
growth.
Figure 24 shows that portions of Arizona, Utah, Wyoming,
Washington, and Oregon have rainfalls from 0 to 10 inches
annually. The ability of an area to lose water by evapo-
transpiration is shown in Figure 25. The greater this value,
the less water becomes available for use. In arid regions the
increased loss may be so great that it significantly dimini-
shes the value of a reservoir used to regulate the water
supply. "*i Figure 26 shows areas in which natural water surplus
35pp. 109, 109.
98
-------
MD
V£>
3867- IS
AVERAGE ANNUAL
PRECIPITATION
Inches
[1 0-1°
mm 10-20
H 20-30
10 30-40
g 40-60
• 60-100
• Over 100
Figure 24. Average annual precipitation'
Lp. 3-2-2
-------
o
o
AVERAGE
ANNUAL PAN
f VAPORATION
Inches
40
| 140-60
60-80
80-100
100-120
Over 120
3«67 16
Figure 25. Average annual pan evaporation
(41
p. 3-2-3.
-------
WATER SURPLUS
OR DEFICIENCY
Inches
Figure 26. Areas of natural water surplus and natural water deficiency141
p. 3-2-H
-------
or water deficiency commonly exist. The values shown have
been computed by subtracting evapc-transplration from average
precipitation. Short-tern seasonal deficiencies can occur
in areas of surplus.
The river and stream runoff in the West is tighly controlled
by appropriation rights. The Appropriation Doctrine developed
and used in the U.S. over the past hundred years states that
the first one who applies water to a beneficial use acquires
the first right to the use of that water regardless of the
location of use and regardless of the ownership of the lands
adjoining the stream.*2 In contrast, the Riparian Doctrine
gives to the owners of the land adjoining a stream the ex-
clusive right to the use of the water. Water for western
irrigation Including ground water also falls under the
Appropriation Doctrine. Variations of the doctrine are also
practiced but they are similarly stringent. Figure 27 shows
present conventions in water rights laws as they apply to
different regions of the country.
The dependable water supply from rivers and streams In the
West is able to keep pace with the water withdrawn and con-
sumed as shown in Figure 28. Water withdrawn is the amount
of water utilized from the water reservoir for any purpose
excluding hydroelectric power. Consumption refers to amount
of water withdrawn but not directly returned to the supply.
The ratio of water supply to water use using the 1980
dependable supply figures is 3.3 for the non-coastal western
states. Obviously higher dependable water supplies exist for
102
-------
o
00
Riparian Right!,
Statutory Regulation
3867-17
California Doctrine -
Appropriation* and Riparian Ki«ht,
Colorado Doctrine -
Appropriation*
Figure 27. Present conventions in water rights law1*2
42.
-------
o
1200
900
600
Of
300
0
RATIO OF SUPPLY/USE = 3.3
RATIO OF CONSUMPTION/
WITHDRAWN =0.414
AVERAGE
ANNUAL
RUNOFF
.9 DEPENDABLE
SUPPLY
(1980)
rnrri, I..AT™
FRESH WATER
WITHDRAWN
(1970)
v ''u'
FRESHWATER
CONSUMED
SUPPLY
Figure 28. Water supply and demand in the non-coastal western states43
^Murray, C. R. Water Use, Consumption, and Outlook in the
U.S. in 1970. J. American Water Works Association. 65:307,
May 1973-
-------
the U.S. as shown in Figure 29. However, the ratio of water
supply to water use is only slightly higher, averaging 3.8.
Where the potential problem exists is in the rate of water
consumption to water withdrawals in the West. Comparing
Figures 28 and 29 it is seen that the ratio of western con-
sumption to withdrawal is nearly twice that of the entire
U.S. (0.414 vs 0.238). This is probably explained by vast
consumptive usage of water for crop irrigation, dust control,
etc.
The variability of major river flow is also a significant
problem in the West. This is a strong indicator of de-
pendable water supply. Figure 30 shows the water resource
regions of the U.S. Table 24 gives figures for mean annual
natural runoff for each region shown in Figure 30. The
average runoffs available for 50%, 90% and 95% of the years
are computed from statistical distributions of annual runoffs
at gaging stations. The closer the 95% figure is to the
mean value", the lesser variability is 'experienced throughout
the year. For example, the average runoff available in 95%
of the years in the humid North Atlantic Region is 69% of
the mean. The arid lower Colorado Region has only 26% of
the mean available 95% of the years. The areas of greatest
variability in annual runoff are in the southwest and west-
central parts of the United States.1*1 In general, potential
water availability in the West from rivers is not very pro-
mising because of prior allocation, and it is not totally
reliable because of great fluctuations in stream flow.
41PP. 3, 2, 6.
105
-------
O
CTN
1200
ID
O
600
300
1200
AVERAGE
ANNUAL
RUNOFF
RATIO OF SUPPLY/USE • 3.8
RATIO OF CONSUMPTION/
WITHDRAWALS-0.238
DEPENDABLE
SUPPLY
(1980)
515
(1955)
FRESH WATER
WITHDRAWN
(1970)
325
FRESH WATER
CONSUMED
(1970) ..
SUPPLY
USE
Figure 29. Water supply an>\ demand In the Ji8 conterminous
.-^3
U3p. 307.
-------
COLUMBIA-
NORTH PACIFIC
Figure 30. Water resources regions for water use
in the United States'41
p. 2-3-
-------
Table 24. ANNUAL NATURAL RUNOFF41
(billions of gallons per day)
Region
North Atlantic13
South Atlantic-Gulf
Great Lakes13 '°
Ohiod
Tennessee
Upper Mississippi
Lower Mississippi
Souris-Hed-Rainyb
Missouri
Arkansas -White-Red
Texas-Gulf
Rio Grandee
f
Upper Colorado
Lower Colorado >e
Great Basin
Columbia-North Paci-
fic13
California8
Conterminous U.S.S
Alaskab
Hawaii
United States6
Mean
163
197
63.2
125
Hi. 5
61). 6
48.4
6.17
5^.1
95.8
39-1
4.9
13.15
3.19
5.89
210
65-1
1,201.
580
•13-3
1,794
50*a
163
188
61.4
125
41.5
. 64.6
48.4
5.95
53.7
93.4
37.5
1.9'
13.15
2.51
-5.82
210
61.1
(h)
(h)
90Ja
123
131
16.3
80.0
28.2
36.1
29.7
2.60
29-9
44.3
15.8
2.6
8,82
1.07 -
3.12
154
33.8
(h) .
(h)
95*a
112
116
' 42.1
67.5
24.1
28.5
24.6
1.91
23.9
33.4
11.1
2.1
7-50
0.85
2.46
138
25.6
(h)
(h)
% of Mean1
69
59
67
54
59
44
51
31
44
35
29
43
56
26
42
66
39
—
__
—
—
aFlow exceeded in indicated percent of years.
Does not include runoff from Canada.
°Does not Include net precipitation on the Lakes
dDoes not include runoff from upstream regions.
eDoes not include runoff from Mexico.
fVirgin flow. Mean annual natural runoff estimated to be 13-7 bgd.
^Rounded.
hNot available.
•"•Using 95% figures.
3-2-6.
108
-------
The most promising source of water for dust control, pipeline
slurry media and coal cleaning operations appears to be under-
ground water. Figure 31 shows major areas of potential ground-
water development. The alluvial basins in the arid far West
are the most promising developmental areas because they are
surrounded by mountains from which they receive runoff
replenishment. Rich coal bearing regions in New Mexico,
Colorado and Utah are included in the alluvium filled valleys.
Portions of Montana and North Dakota are underlain for
hundreds of miles by water abundant rock. This partly ex-
plains the increased interest in North Dakota as a major
source of gas-from-coal plants which require enormous quanti-
ties of water. Wyoming appears to have less water potential
than the other states included in this study. An example
of large-scale use of underground water for coal related
processes is the Black Mesa pipeline in Arizona. A supply
of 2000 gpm was determined to be needed to transport coal
from the mine to the power plant 273 miles away.1*4 Wells
to a depth of 3800 feet supply the water from Navajo sand-
stone. The estimate of water in this one location is about
10,000,000 acre-feet. The 35-year life of the pipeline may
require that upwards of 100,000 acre-feet be withdrawn,
leaving 99% of the original water in the ground.
Water supply in the West is not without substantial problems.
Table 25 shows existing and emerging water management prob-
lems for various regions of the U.S. Besides, inadequacy of
runoff water and ground water shortage depletion in non-
alluvial basins, increasing salinity of water and sedimen-
* Anon. The Black Mesa Plan: Energy Today, Better Land
Tomorrow. Coal Age. 78:82, March 1971.
109
-------
ALLUVIAL BASIN
Figure 31. Major areas of potential ground
water development **]
-------
Table 25. EXISTING AND EMERGING WATER MANAGEMENT
PROBLEMS IN THE UNITED STATES41
Adequacy Ground-
of annual water
natural storage
Region runoff depletion
North Atlantic
South Atlantic-Gulf
Great Lakes
Ohio
Tennessee
Upper Mississippi
Lower Mississippi
Souris-Red-Rainy
Missouri
Arkansas-White-Red
Texas-Gulf
Rio Grande
Upper Colorado
Lower Colorado
Great Basin
Columbia-North Pacific
California
Alaska
Hawaii
Puerto Rico
C
D
C
C
D
C
D
B
B
B
B
A
A
A
A
C
B
D
D
D
C
C
D
D
D
D
D
D
B
A
A
A
D
A
C
C
B
D
C
D
Water Quality
Wastes
A
B
A
B
C
B
C
C
C
C
B
B
C
B
B
C
B
C
C
r;
Heat
A
C
A
B
C
B
D
D
C
D
C
D
D
D
D
B
C
D
D
D
Salinity
D
D
D
D
D
D
D
C
C
A
B
A
C
A
C
D
B
D
D
D
Sediment
C
B
C
C
C
C
A
D
B
B
B
A
B
A
C
D
C
D
D
B
Beach,
shore, and
Flood Watershed rlverbank
damages lands erosion
C
B
D
B
C
B
B
B
A
B
C
C
D
C
D
B
B
C
D
D
C
B
D
C
C
C
B
D
B
B
B
B
C
B
C
C
B
D
C
B
3
A
C
D
D
B
B
C
B
A
B
C
D
C
D
C
B
B
B
C
Wetlands
B
A
C
D
D
B
B
B
B
B
B
D
D
D
C
3
C
C
D
D
A - Severe problem in some areas or major problem In many areas.
B - Major problem in some areas or moderate problem in many areas.
C - Moderate problem in some areas or minor problem in many areas.
D - Minor problem in some areas.
^pp. 1-29.
-------
tation appear to limit industrial activity to selected
regions which may not correlate with the vast deposits of
western coal. Added to these problems is the fact that the
coal deposits themselves may form a portion of the aquifer
system. The effect of water shortages, unless counter-
measures are taken, will be an adjustment in the pattern of
economic activity. An increase in the use of saline water
in the West is expected as more readily available supplies
of fresh water are depleted. Contamination of this sort can
be minimized by the increased use of underground water.
Resource management of all sources of water will ensure the
continued success of western coal mining. Consequently,
water supply in the West does not appear to be a limiting
factor in supplying coal to midwestern and interior province
states.
A more detailed investigation of future water availability
is beyond the scope of this report. One currently ongoing
western water resource investigation that promises the
development of a general plan to meet the future water needs
of eleven western states is the Westwide Water Study (W¥S)
undertaken by the Department of the Interior.1*5 The area
of the study encompasses eight of the ten important coal
bearing states in this report; namelys Arizona, Colorado,
Montana, New Mexico, Oregon, Utah, Washington, and Wyoming,
The WWS is a full and complete reconnaissance to develop the
general plan. The objectives of this study, which was started
in 1968 and will be completed by June 1977, are as follows:
(1) to project the West of the future with regard to'popu-
lation, industry,, agriculture, environment and social makeup;
(2) to determine water supply from all available sourcesj (3)
l+5Pairchild, W. D, The Westwide Water Study. J. Amer.
Water Works Ass. 63:706-710, November 1971.
112
-------
to translate projected future conditions into water
requirements and balance them against available and poten-
tial water supplies; and (4) to develop a general plan to
meet these needs and in optimum manner. The Colorado River
will be studied to determine the most economically acceptable
means of augmenting its supply. Importation of water from
natural river drainage areas located in other than the Colorado
River Basin states is excluded.
Potential sources for the development of new water supplies
include weather modification, desalination of seawater and
brackish water, geothermal development, and waste water
reclamation. Preliminary studies indicate that an additional
annual runoff of up to 1.8 million acre-feet could be produced
by winter cloud seeding in the Colorado River Basin alone.1*5
Production costs for this augmentation are estimated at
$1.00-1.50/acre-ft. Desalting existing water supplies
promises to be a potential source of augmentation if done
on a large scale and if plant brine effluents can be dis-
posed of safely. It is estimated that 2.5 million acre-ft/yr
of new water could be produced for 100 years from geothermal
wells. Water would have to be recovered from geothermal
brines by desalting. The WWS forecasts geothermal wells
coupled with power plants and desalting units if the study
advances to the point where a reliable estimate of this
potential water supply can be predicted. The WWS has begun
to inventory waste water sources and the prospects for their
utilization. One use for treated waste water is crop irri-
gation which consumes a major amount of water. Considerable
attention has been given to the total reclamation and reuse
of domestic and industrial waste water as a supplement to
present water supplies.
•*5p. 708.
113
-------
3.5 WESTERN COAL COMPOSITION AND ASSORTED PHYSICAL
AND CHEMICAL PROPERTIES
Western coals possess properties characteristically different
from eastern coals. Besides being inherently low in sulfur,
they are generally more prone to fouling and have lower
calorific value per pound. A large majority of the coal-mined
in the West'is of the subbituminous- and lignitic ranks and is
surface mined. The ASTM ranking classifications are given
in Table 26 which ,shows that subbituminous coals have a Btu
per pound range from 8300 to 11,,500 on a moist., mineral
matter-free basis. .Lignite ranges from below 6300 to 8300 •
Btu per pound. Figure 32 is a graphical representation of
all coals and indicates, that subbituminous coals have lower
fixed carbon and higher inherent moisture than higher ranking
bituminous and anthracite coals.
Statewide values for coal composition, heating value, ash
softening temperature, rank index and ash analyses are pre-
sented here . Additional combustion process related properties
such as Hardgrove grindability index and total carbon loss
may be found in Section 4 of this report. This section also
relates these coal properties to combustion behavior. De-
tailed coal analysis data compiled for individual mines and
coalfields are reported in 'Appendix G.
Table 27 shows representative minimum, maximum and average
values of coal characteristics for 20 states including eight
western states. Rank .index is included and is -defined as:
RI = Rank Index = ., ., ,.n Btu (dry basis)
Volatile matter (dry basis) x 10 ^ '
-------
Table 26. CLASSIFICATION OF COALS BY RANK3-'1*6
Ul
Class
I. Anthracitic
II. Bituminous
III. Sub-bituminous
IV. Lignite
Rank
A 1. Meta-anthracite
A 2. Anthraoite
A 3. Semianthracite
B 1. Low volatile bituminous
coal
B 2. Medium volatile bitumi-
nous coal
3 3. High volatile A bitumi-
nous coal
B 4. High volatile B bitumi-
nous coal
B 5. High volatile C bitumi-
nous coal
C 1. Sub-bituminous A coal
C 2. Sub-bituminous B coal
C 3- Sub-bituminous C coal
D 1. Lignite A
D 2. Lignite B
Fixed Carbon
Liir.its, %
(Dry, Mineral-
Matter—Free
Basis)
Equal or
Greater
Than
98
92
86
78
69
—
—
—
™*~
Less
Than
98
92
86
78
69
—
—
—
Volatile Matter
Limits, %
(Dry, Mineral-
Matter-Free
Basis)
Greater
Than
2
8
14
22
31
—
—
—
Equal
or Less
Than
2
8
14
22
31
—
—
Calorific Value
Limits, Btu/lb
(Hoist,b
Mineral-Mat <:er-
Free-3asis)
Equal or
Greater Less
Than
—
—
Il4,000d
i3,oooa
- 1 11,500
\ 10.500e
—
10,500
9,500
8,300
6,300
Than
::
—
—
—
14,000
13,000
11,500
11,500 j
10,503 /
9,500 \
8,300 \
6,300 '
Agglomerating
Character
'lonagglomerat ing
Coranonly
agglomerating
Agglomerating
Nonagglomeratin
15 500 moist, mineral-matter-free British thermal units per pound.
"Moist refers to coal containing its natural inherent moisture but not Including visible «ater on the surface of the coal.
°If agglomerating, classify in low-volatile group of the bituminous class.
dCoals having 69* or nore fixed carbon on the dry, mineral-matter-free ,asis shall be classified according to fixed carbon,
regardless of calorific value.
"It is recognized that there may be nonagglomerating varieties in these groups of the bituminous class, and t:,are .re notable
exceptions in high volatile C bituminous group.
"6An0n. Steam/Its Generation and Use. 38th Edition. New York, Babcock & Wilcox Company, 1972. pp. 5-11.
-------
- .
I
.
s ram
.
-------
Table 27. RANGE OF COAL CHARACTERISTICS'47.1*8
3ttt«
AltbiM
Arltona
Colorado
IlUnoii
Indian*
Iowa
lU.r.3M
Kentucky
Missouri
Ho n tint*
Hen Meileo
Nortn Dakota
Ohio
Oklahoma
Pennsylvania
Tenneaaee
Otah
Kaihlntton
West Virginia
Vyoalnf
Mln.
Ave.
Mai.
Ave
Mln.
Ave.
Mai.
Mln.
Mai!
Mln.
Ave.
Mai.
Mln.
Ave.
Mai.
Mln.
Ave.
Mai.
Mln.
Ave.
Mai.
Mln.
Ave.
Mai.
Mln.
Ave.
Mai.
Mln.
Ave.
Mai.
Bin.
Ave.
Mai.
Mln.
Ave.
Mai.
Mln.
Ave.
Mai.
Mln.
Ave.
Mai.
Mln.
Ave.
Mai.
Mln.
Ave.
Mai.
Mln.
Ave.
Mai.
Mln.
Ave.
Mai.
Mln.
Ave.
Mai.
Mois-
ture
2.9
4.7
12.5
11.7
4.6
12.9
22.5
4.8
21.9
8.0
11.4
19.0
9.6
15.6
19.2
3.6
4.6
5.9
2.0
6.1
11.9
11.1
12.1
13.2
8.0
25.1
"3.0
11.7
12.7
13.7
33.3
3B!6
3.2
5.9
8.2
1.0
3-5
5.0
1.0
3.7
12.0
1.8
3.0
3.8
2.8
5.3
8.7
4.8
5.0
5.2
1.5
3.6
6.5
15.5
20.1
23.0
Volatile
Hatter
29.7
37.7
42.0
44.4
37.2
39.6
43.3
35.3
41 0
38.1
42.7
45.3
38.1
40.9
48.1
36.6
39.5
40.6
33.6
39.2
"3.7
44.0
«4.3
330
39.2
42.0
44.1
44.2
44.3
4U9
44.2
39.1
41.8
45.2
39.4
«2.2
45.0
16.0
43i3::
29.0
31.0
36.8
40.5
«5.2
47.0
38.0
33.0
38.0
29.1
36.4
40.4
41.7
46! 4
Carbon
51.9
55-9
62.7
47.1
46.6
51. »
56.1
44.5
55.7
44.4
47.5
52.4
32-3
41.0
«6.6
49.3
50.5
53.3
48.2
5».3
60.7
46.7
47.1
»7.4
44.0
51.1
53.3
46.6
47. »
49.6
46.8
49.3
49.2
45.3
»9.7
54.1
47.9
48.7
49.6
46.3
57.0
77.0
51.8
57.3
61.0
44.4
50.1
53.5
46.0
46.2
46.4
53.0
56.7
65.6
47.1
50.8
54.2
Aah
2.5
6.1
It. 6
8.5
5.1
1.6
14.6
6.1
11.5
7.7
9.8
11.6
13.1
19.1
29.6
8.5
11.0
11.3
3.6
7.8
17.7
8.9
8.9
9.0
10.7
16.0
7.1
8.2
9.3
7.9
9.8
13.1
6.1
9.«
13.6
7.1
9.0
11.0
5.8
9.6
21.0
10.0
11.7
14.6
5.7
7.3
13.6
15.6
15. t
16.0
2.8
7.9
16.5
3.5
5.7
7.9
3
0.6
1.2
2.0
0.4
1:1
1.1
1.5
1.1
3.2
4.5
2.5
4.5
10.3
2.3
3.8
0.6
2.2
3-9
4.1
1.0
2.3
0.7
0.4
0.7
1.0
2.1
2.7
3-2
3.5
0.7
2.3
8.1
0.6
1.3
1.2
0.3
0.5
0.9
0.3
0.3
0.6
1.0
1.6
0.5
0.8
1.0
,
:>
-
-
—
-
4.0
1.5
5.3
5.1
5.3
5.4
5.5
-
4.5
5.2
E
5.1
1.5
4.9
5.1
L'
E
E
s'.i
7.0
5.0
c
73 3
—
—
~
52.6
62.3
69.7
72.3
72.6
73.3
79.5
-
68.1
70.9
E
74.5
767 e
73.7
76.7
79.5
73^5
E
—
73.1
13.0
72.1
,
:•
-
-
«
E
0,9
1.3
1.6
1.2
1.6
-
1.3
1.3
-
1.5
1.5
1.1
1.4
1.5
£•
E
—
1.2
1.5
1.1
:<
0
t~.7
14 6
—
--
—
4.3
6.6
3.1
3.7
4.3
7.2
=
'.4.7
12.6
-
6.2
5.6
4.9
5.6
6.9
7.2
E
—
1.9
5.3
7.9
11.1
St-j
12160
13280
14150
10T3D
11C50
11270
10300
12313
1C670
11540
12370
9350
9590
10970
8350
9580
10970
11213
12 BOO
14150
11390
11530
11683
*?90
9680
11030
10790
6'00
12560
13*40
12730
13370
10750
13320
14420
12370
12970
13350
11370
11430
12953
11630
11670
11720
11930
13130
14390
9540
10110
10700
Ash
Softening
Teaptrat ure
2130
2320
2680
22«0
2910*
2000
2090
218>
2303
2333
2700
1913
2360
2^3
1980
2023
23'Q
2133
2113
2301
2023
2133
2350
2 380
2433
2»90
2080
2910«
1993
2243
2520
--
--
2020
2413
2910«
2380
2460
2910*
2110
2250
2420
2590
2910«
2070
2543
2910«
2450
tank
33.0
36.3
45.7
34.5
24.7
27.4
3J.2
24.3
28.9
35.1
24.1
26.9
31.0
22.3
23.7
24.9
30.7
33.2
35.5
27.7
31.!
42.2
25.7
26.2
26.7
17 • '
22!?
33.4
24.5
25.4
26.2
15.2
16.9
18.2
27.1
30.1
34.0
29.8
31.1
32.}
30.9
45-;
88.9
35.1
40.0
46.0
26. »
28.7
31.7
30.6
30.7
30.8
33.3
38.0
«9.9
22.3
22.9
23.7
?" e «- «"•» « Wn«
^
117
-------
The importance of rank index values is explained in Section
4.
Moisture and Btu values given are "as received." All other
properties are on a dry basis. Averages are arithmetic es-
timates of available data. Coal rank as a function of Btu
content can be found in Table 26. Oxygen percentage is also
a general indication of rank since it is usually true that
rank goes down as oxygen percentage increases. In Table 26,
compositions are reported in weight percent, calorific
values in Btu per pound and ash softening temperatures in
degrees Fahrenheit.
Ash analyses reported as oxides are shown in Table 28.
Averages were computed as non-weighted arithmetic means.
Trace elements typically found in U.S. Coal ash from all
regions are bariums beryllium9 boron, cadmium, chromium,
cobalt, copper., fluoride, gallium, germanium, lanthanum,
leads lithium, manganeses mercury, molybdenum, nickel,
scandium, selenium, strontium, tin, vanadium, ytterbium,
zinc and zirconium.50 Also present on a less widespread
basis are arsenic, bismuth, cerium, neodymium, niobium
(columbium), rubidium and thallium.
Trace element contents in coal ash for three areas of the
U.S. are shown in Table 29 and the majority of these plotted
in Figure 33 along with crustal abundance of the elements.
With few exceptions, trace elements are more abundant in coal
than they are in the earth's crust or soil. When compared
50Abernethys R. P., M. J. Peterson, and F. H. Gibson,
Spectrochemical Analyses of Coal Ash for Trace Elements.
Bureau of Mines Report of Investigations. 7281. 1969.
p . 1.
118
-------
Table 28. TYPICAL ASH COMPOSITION"
(Wt.-j5)
?tate
( of Moisture
Fret Coal
Ash
\ of Molstur<
Free Coal
Sulfur
S102
A1203
Fe20j
TiOj
P,05
CaO
M*o
Na20
K;O
so,
NORTHERN (1REAT PLAINS PROVINCE
Colorado
Montana
New Mexico
North Dakota
Utah
Wyoming
Mln.
Ave.
Max.
Mln.
Ave.
Max.
Mln.
Ave.
Max.
Mln.
Ave.
Max.
Mln.
Ave.
Max.
Mln.
Ave.
3.0
10.0
19.?
4.2
12,6
19.3
2.9
10.5
16.3
7.5
11.8
16.9
5.7
7.7
9.6
6.4
10.1
14.4
0.4
0.7
1.1
0.4
0.6
0.9
0.6
1.3
3.2
0.5
1.0
1.5
0.1
0.8
2.2
0.6
1.2
1.8
31.8
50.1
71.8
21.9
35.4
53.6
28.9
49.2
61.9
15.0
26.3
40.4
39.4
51.4
63.2
21.5
31.5
38.6
15.2
26.8
34.2
13.8
21.5
31.9
14.3
21.8
30.0
8.0
12.1
16.8
9.1
15.1
20.3
14.2
16.9
19.6
3.2
6.1
11.9
2.9
1:1
J:i
27.3
4,1
6.9
10.1
3.7
7.4
19.3
9.0
9.6
10.3
1.0
1.3
1.7
0.6
0.8
1.2
0.9
1.1
1.3
0.6
0.7
0.9
0.6
1.0
1.3
0.9
1.3
1.8
0.01
0.5
2.8
0.02
0.4
0.76
0.02
0.06
0.12
0.04
0.2
0.42
0.03
0.6
1.4
0.21
0.36
0.5
6.2
12.8
1.8
13.4
31.4
1.7
6.4
14.0
14.5
21.1
36.0
3.5
11.8
21.9
9.''
20.1
30.8
0.4
1.1
2.9
1.4
4.6
10.4
0.8
2.0
4.2
3.3
6.4
10.8
0.3
3.3
7.6
4.4
4.5
4.7
0.7
3.0
0.1
2.8
8.1
0.1
0.7
2.2
0.5
4.4
8.2
0.4
1.7
4.3
0.1
0.1
0.2
0.3
0.8
0.3
0.7
1.8
0.1
0.6
1.1
0.1
0.3
0.6
0.1
0.6
1.4
0.5
0.5
0.6
5.2
15.1
2.4
13.3
26.2
0.5
4.7
17.3
16.6
20.6
27.4
1.8
6.0
8.6
14.4
15.2
16.1
COAST PROVINCE
Washington
Mln.
Ave.
Max.
6.1
10.6
22.4
0.4
0.5
0.5
37.2
45.9
54.1
29.7
33.5
38.2
2.8
5.6
9.2
2.3
4.7
1.7
2.6
3.1
7.6
1.5
2.6
0.7
1.5
1.1
1.7
3.6
10.5
Arkansas
Illinois
Indiana
Iowa
Kansas
Missouri
Mln.
Ave.
Max.
Mln.
Ave.
Max.
Mln.
Ave.
Max.
Mln.
Ave .
Max.
Mln.
Ave.
Max.
Mln.
Ave.
4.0
8.3
12.5
7.7
10.0
17.1
6.1
9.3
14.0
10.8
13.4
16.0
9.2
10.5
11.7
10.1
11.7
12.8
2.5
2.5
2.5
2.4
1:1
0.7
2.9
4.5
5.0
5.3
3.3
4.0
4.7
4.2
1.6
5.2
24.4
24.8
25.2
36.0
45.5
54.5
30.7
46.9
55.2
29.0
34.3
39.6
35.9
38.2
40.5
37.9
42.2
45.4
12.1
19.7
27.1
15.4
19.1
23.2
16.1
22.8
31.6
12.1
13.9
15.8
11.2
16.3
18.5
14.5
15.8
16.8
20.3
23.1
26.5
16.3
23.3
35.4
7.0
20.7
40.7
32.5
33.4
34.3
25.0
32.7
40.5
25.6
31.1
41.0
0.6
0.9
1.3
0.6
0.9
1.5
0.8
1.1
1.3
•0.8
0.9
0.6
0.7
0.6
0.7
0.8
1.1
1.3
0.03
0.16
0.44
0.02
0.14
0.59
0.02
0.56
0.05
0.27
0.02
0.10
0.1
7.4
13.1
18.8
1.7
5.2
10.4
1.7
3.4
8.4
4-3
9.7
15.0
1.8
6.7
11.7
1.7
4.9
7.0
4.9
5.4
0.4
0.9
1.3
0.5
0.9
1.5
0.9
1.3
1.6
0.3
0.5
0.8
0.4
0.7
0.8
1.5
2.1
0.1
0.4
0.6
0.2
0.5
1.1
0.2
0.5
0.8
0.2
0.3
0.5
0.1
0.1
0.2
1.3
1.7
2.0
2.6
1.3
2.4
3.3
1.2
1.2
0.4
1.0
1.6
1.3
2.1
3.0
10.3
0.8
1.7
2.8
0.2
1.1
3.1
2.4
3.1
3.7
1.4
2.7
4.0
1.1
2.5
3.5
Alabama
Kentucky
Ohio
Pennsylvania
Tennessee
West virgin!
Mln.
Ave.
Max.
Mln.
Ave.
Max.
Mln.
Ave.
Max.
Mln.
Ave.
Max.
Mln.
Ave.
Max.
Mln.
Ave.
Max.
4.5
9.1
17.0
2.2
8.5
15.6
4.6
11.5
17.2
1:1
13.4
4.B
10.4
17.2
3.2
9.0
27.9
0.8
1.6
3.8
0.6
2.1
3.5
1.2
3.6
6.9
0.7
1.9
6.3
0.6
2.0
4.1
0.5
1.8
6.0
23.9
43.7
54.0
31.6
48.7
57.9
30.2
43.3
56.1
26.9
43.5
57.7
33.6
47.7
56.5
25.8
46.1
64.5
18.4
26.4
33.3
18.8
26.2
34.5
18.8
22.8
30.2
18.2
26.3
32.7
18.6
26.3
32.7
14.1
28.5
41.6
5.3
19.9
4;.o
4.1
16.5
30.4
8.6
27.9
45.2
5.1
22.9
52.5
6.1
15.9
41.6
2.1
16.9
»8.2
0.6
1.1
1.8
0.8
1.3
2.3
0.6
1.0
2.2
0.7
1.1
1.7
0.9
1.2
1.7
0.5
1.3
2.3
0.23
0.57
0.04
0.15
0.48
0.04
0.20
0.91
MOO
Co JffO
0.13
0.79
1.8
0.02
0.33
3.0
3.0
12.4
0.9
2.25
5.7
0.4
2.0
4.8
1.2
2.52
9.1
1.7
1.9
2.8
0.4
2.7
12.7
1.3
2.1
0.3
1.0
2.1
0.2
0.7
1.7
0.2
0.6
1.1
0.7
1.2
1.6
0.2
0.81
3.8
0.27
0.5
0.2
0.37
3.0
0.1
0.2
0.1
0.1
0.2
0.5
0.2
0.3
0.5
0.1
0.1
2.1
0.9
2.1
4.0
0.9
2.3
4.1
0.4
1.5
2.7
0.6
1.7
3.6
1.0
2.7
3.3
0.2
1.7
3.5
2.1
4.7
0.2
1.6
6.6
0.2
1.2
3.6
0.2
1.4
3.6
0.8
1.6
3.0
0.3
2.0
9.6
"'Anon. Major Ash Constituents In U.S. Coals
of Investigations. 7240. 1969. pp. 4.9.
"Modified from data In reference *'.
Bureau of Mines Report
119
-------
Table 29. AVERAGE TRACE ELEMENT CONTENT IN ASH OF COAL
FROM THREE AREAS, AS WEIGHT PERCENT3*50
Element
Barium
Beryllium
Boron
Chromium
Cobalt
Copper
Gallium
Germanium
Lanthanum
Lead
Lithium
Manganese
Molybdenum
Nickel
Scandium
Strontium
Tin
Vanadium
Ytterbium
Yttrium
Zinc
Zirconium
Arsenic
Bismuth
Cerium
Neodyralum
Niobium (columblum)
Rubidium
Thallium
Average Trace Elementj % o
Ash
Average Ash,J of Dry Coal
Average Trace Element, % o
Dry Coal
Number of Samples
'rustal
abun-
dance''
O.OK25
.00028
.0010
.0100
.0025
.0055
.0015
.00015
.0030
.0013
.0020
.0950
.00015
.0075
.0022
.0375
.0002
.0135
.00034
.0033
.0070
.0165
.00018
.00002
.0060
.0028
.0020
.0090
.00005
Approx-
imate
lower
limit of
detec-
tion0
0.002
.0001
.0002
.0001
.0020
.0001
.0002
.0003
.01
.0001
.0001
.0001
.0001
.0001
.002
.001
.0001
.0001
.0001
.001
.005
.005
.005
.0001
.02
.01
.001
.001
.0005
Eastern Province
Fre-
quency
of
detec-
tion
100
100
100
100
100
100
100
99
92
100
100
100
99
100
100
100
100
100
100
100
98
100
67
82
31
29
73
97
13
Average
trace
element
content
of aah
0.0876
.0012
.0265
.0230
.0181
.0128
.0071
.0048
.0115
.0055
.05811
.0260
.0082
.0209
.0089
.1052
.0019
.0336
.0007
. 01*12
.0230
.0701
.0159
(.0107)
.0002
(.0002)
.0238
(.0074)
.0213
( .0062)
• 0053
(.0039)
.0239
(.0232)
.0019
( .0008)
.6651
9.3
.0618
600
Interior Province
Fre-
quency
of
detec-
tion
100
100
100
100
98
100
100
100
86
100
100
100
99
100
100
100
99
100
100
100
100
100
111
77
11
10
88
100
49
Average
trace
element
content
of aah
0.0399
.0014
.0731
.0221
.0193 .
.0089
.0039
.0104
.0131
.0131
.0235
.0325
.0073
.0262
.0069
.0658
.0019
.0325
.0005
.0118
.0743
.0825
.0119
(.001(9)
.0001
( .0001)
.0214
( .0024)
.0183
( .0018)
.0055
(.0048)
.0276
(.0276)
.0008
(.0004)
.6568
10.5
.0690
123
Fre-
quency
of
detec-
tion
100
100
100
100
98
100
100
95
81
100
100
100
100
100
97
100
100
100
100
100
93
100
16
83
13
15
85
58
9
Average
trace
element
content
of ash
0.1'»67
.0006
.0^29
.0066
.0097
.0047
.0033
.0017
.0128
.0029
.0168
.0212
.0020
.0054
.0052
.1456
.0017
.0152
.0003
.0076
.0258
.0850
.0073
(.0012)
.0001
( .0002)
.0233
(.0031)
.0295
( .0041)
.0053
( .0045)
.0064
(.00371
.0005
( ,00005)
.6466
9.8
.063H
104
Averages calculated for number of samples in which element was detected, except that averages in
parentheses were calculated for all of the samples t
-------
0.10
.08
1C
< .06
U_
0
H-
I'.-i
CJ
ac.
LU (14
Q_ .IKt
.02
1
.
-
- 1
-
"
<
"
1
f
^
71
:;|
-
|
hkl
V/////////////A
1
;
^
0^1
KEY
-
EASTERN PROVINCE
E«3 INTERIOR PROVINCE
a WESTERN STATES
• CRUSTAL ABUNDANCE
ft
.
'
-•
I
|
|
i
-
li
:
; R
1
1
~T
"
-
-
1"
B Be Co Cr Cu Ga Ge La Li Mn
Sn
Figure 33. Average trace element content in ash of
coal from three areas compared with crustal abundancea>5
lBarium and strontium not included
50,
-------
to eastern and interior province coals, it appears that
western coals contain similar amounts of total trace elements
in ash and in dry coal. Figure 34 shows par-per-million
levels in coal of some trace elements not listed in Table 29,
notably cadmium, mercury and selenium. Values obtained are
circled for western states. These elements would not
normally be detected in ash samples due to their higher
volatility.
Although total trace element content in western coal ash
(0.6466*) is nearly equivalent to interior and eastern
province coal ash contents (0.6568? and 0.6651*. respectively)
the distribution of each element is notably different. Exami-
nation of Table 29 shows western barium, strontium and
zirconium levels greater than those in eastern or interior
province coals. All other elements in Table 29 either are
or considerably lower levels or are unchanged for western
coals. Figure 34 shows the presence of cadmium and selenium
indigenous only to western coals, with mercury levels
comparable for all U.S. coals.
Table 30 presents trace element ash averages of western
coal for eight of the ten states Included in this study.
Washington coal ash samples had the largest quantity of
trace elements. It is difficult to extend these results
to all coals in a particular state because of the limited
number of samples tested (104). We have tried to Investigate
whether the total trace element content in coals follows
some recognizable trends. plgure 35 is a plot of total
trace element content in coal against ash content of coal
based on data from Table 30. First, no correlation seems to
exist relating ash percent in coal to trace element content.
Second, if the states are ranked from north to south, it
122
-------
ARSENIC
BERYLLIUM
BORON
CADMIUM (
CHROMIUM
COBALT
COPPER
FLUORIDE
LEAD
MERCURY
NICKEL
SELENIUM
TIN
VANADIUM
ZINC
1 1 — 1 — 1 1 1 1 1
£ ©
f)jj S*0
0
" 5=
W a
©
(A) °'-*r*
©
. ill} — (•
m — (^p—
©
©
-
• ' ' — 1 1 1 1 1
' n "0
*5±UD
MS
^T^
— "-'Q
• " ' •
^r -
-* . a JD
i ~ i ii r LLJ_
116)
0.1
SYMBOL REGION
1.0 10.0
PARTS PER MILLION ON COAL, BY REGION
STATES INCLUDED
APPALACHIAN (A)
INTERIOR-EASTERN (IE)
INTERIOR-WESTERN (IW)
WESTERN (W)
PENNSYLVANIA, OHIO WEST VIRGINIA, MARYLAND
VIRGINIA, EASTERN KENTUCKY. TENNESSEE,
ALABAMA, (AND GEORGIA)
ILLINOIS, INDIANA, WESTERN KENTUCKY,
MICHIGAN
IOWA MISSOURI, NEBRASKA, KANSAS,
OKLAHOMA, ARKANSAS, TEXAS
WYOMING, IDAHO, UTAH, COLORADO,
NEW MEXICO, ARIZONA, WASHINGTON
> SOUTHWESTERN (SW) UTAH, COLORADO, ARIZONA, NEW MEXICO
* NORTHERN GREAT PLAINS (N) MONTANA, NORTH DAKOTA. SOUTH DAKOTA
Figure 34. Trace element concentrations in coal51
51Cowherd, C., and J. L. Spigarelli. Hazardous Emission
Characterization of Utility Boilers - Prelimiary Test
Plan. Midwest Research Institute. Kansas City, Missouri.
August 1974. p. 7.
123
-------
Table 30. AVERAGE TRACE ELEMENT CONTENT IN ASH
OP COALS FROM WESTERN STATES, PERCENT OF ASH50
Element
Barium
Beryllium
Boron"
Chromium
Cobalt
Copper
Gallium
Germanium
Lanthanum
Lead
Lithium
Manganese
Molybdenum
Nickel
Scandium
Strontium
Tin
Vanadium
Ytterbium
Yttrium .
Zinc
Zirconium
Average Trace
Element % of Ash
Average Ash % of
Dry Coal
Average Trace
Element % of Dry
Coal
Number of Samples
Arizona
0.0400
.0010
.0500
.0100
0
.0050
.0050
.0050
0
.0010
.0200
.0100
.0010
.0050
.0010
.1000
.0010
.0100
.0001
.0100
.0100
.0*400
.3281
9.7
.0318
1
Colorado
0.0795
.0006
.0494
.0019
.0104
.0019
.0032
.0019
.0129
.0031
.0095
.0216
.0018
.0053
.0056
.0974
.0023
.0125
.0003
.0083
.0362
.0872
.4588
9-2
.0422
10
Montana
0.3000
.0012
.0175
.0021
.0061
.0025
.0039
.0025
.0097
.0038
.0215
.0456
.0038
.0026
.0034
.2612
.0009
.0097
.0001
.0060
.0337
.0612
.8296
12.6
.1045
8
New
Mexico
0.2250
.0008
.0361
.0091
.0126
.0050
.0034
.0032 .
.0150
.0040
.0138
.0165
.0017
.0069
.0068
.0800
.0016
.0213
.0005
.0085
.0164
.0911*
.5796
11.8
.0684
14
North
Dakota
0.2650
.0002
.0337
.0034
.0057
.0013
.0020
.0006
.0096
.0022
.0095
.0300
.0032
.0014
.0045
.2612
.0013
.0094
.0004
.0060
.0250
.0662
.7418
12.0
.089
8
Utah
0.1122
.0003
.0861
.0088
.0066
.0038
.0030
.0008
.0131
.0024
.0283
.0157
.0011
.0051
.0037
.1457
.0013
.0117
.0002
.0067
.0109
.0861
.5536
7.0
.0387
23
Washington
0.1714
.0004
.0314
.0121
.0217
.0121
.0059
.0009
.0133
.0025
.0277
.0121
.0026
.0114
.0089
.3071
.0009
.0429
.0004
.0094
.0243
.1286
.8480
12.7
.1077
7
Wyoming
0.196?
.0028
.0417
.006?
.0060
.0050
.0017
.0018
.0050
.0007
.0217
.0160
.0025
.0017
.0040
.1167
.0(112
.0167
.0003
.0053
.0425
.0450
.5417
8.7
.04711
3
11.
12*1
-------
ro
~2 12.0
X
I
o
^ 10.0
2 9.0
UJ
8.0
LU
O
7.0
S 6.0
i—
* 5.0
o
-------
appears that trace element content generally increases in
the northerly direction (Figure 36). Due to the variability
of any type of coal data it appears impossible to completely
verify these conclusions until more data are made available.
Generally, a higher coal total sulfur content is accompanied
by higher iron content. This is primarily due to iron and
sulfur occuring in the form of pyrite, FeS2. Additional
significant conclusions and correlations relating to
trace and minor elements in coal and coal ash made by Magee
et al are reproduced below.52
1. The amount of sulfur in coal is moderate in the
Appalachian region, higher in the interior region
(east and west), and lower in all the western states
2. Trace element concentration as a whole correlates
only moderately with geographical location, and not
at all with coal rank. Boron, which is high in
lignites and lower in high rank coals, is an ex-
ception.
3. The amount of some trace elements is commonly high-
est in the top and bottom few inches of a bed, and
at the edges of a coal basin (Ge, Be, Ga, and B at
the bottom only). These variations are frequently
greater than the differences between the averages
for different beds. Other elements (Cu, Ni, Co)
show no such correlation.
52Magee, E. M., H. J. Hall, and G. M. Varga. Potential
Pollutants in Fossil Fuels. Esso Research and Engineering
Co. Linden, New Jersey, June 1973. pp. 70-72.
126
-------
ro
CM
2 12.0
x
< 11.0
o
o
5 10.0
1 9.0
GJ 8.0
LU
O
£ 7.0
i—
£ 6.0
^ 5.0
4.0
3.0
o
o
M
Q£.
O
O
o
o
•SOUTH-
• CENTRAL-
NORTH
K^
/<:/
f^1
Figure 36. Regional trace element distribution'
a
A plot of Table 30.
-------
4. Different elements tend to be concentrated at
different parts of a bed or basin, probably depen-
ding on the geochemical processes involved in the
formation of the coal.
5. Those elements which tend to be concentrated in
coals (S, Ge, Be, B, Ga) are associated primarily
with the organic portion of the coal. They also
show the largest variance in average concentrations
between different major producing areas (germanium,
e.g., is high in Illinois).
6. The usual amounts (concentrations) of some 20 trace
elements present are about 5-10 ppm, in the (overall
range 1-50 ppm. B and F are higher, about 10-200
ppm, and Hg is lower, about 0.04-0.4 ppm.
7. Most trace elements are present in concentrations
which fall within a narrow range, varying by a
factor of 3 or less in the averages for different
basins or areas. This range is close to their
average crustal abundance, which usually lies
between the concentration in ash. Boron and
germanium in coal are high cor.pared to crustal
abundance, and only a few elements such as manganese
are low.
8. The selection of a completely "non-polluting" coal
is not possible, in the general case. For a given
amount of ash, coals which are low in any one group
of elements must be correspondingly high in others.
The definition of non-polluting depends directly on
the decision as to which elements are of concern
and which are not.
128
-------
9. Trace element variations between coals in different
areas often reflect differences in the source
rocks which contributed the elements to the coal-
forming swamps, and the distance of the source
rocks from the swamps. In certain areas, e.g.,
the Illinois basin, this shows an instructive geo-
graphical pattern.
10. Surface outcrops or samples weathered otherwise by
exposure may not be indicative of trace element
concentrations in the coal at depth. Surface oxi-
dation creates active sites on the coal, with which
minor elements in flowing water can selectively
react.
11. The elements present in the largest amounts, as
minor components of the coal rather than as traces
only, are the common constituents of surface waters
and rocks: silicon, aluminum, iron, sulfur, phos-
phorus, sodium, potassium, calcium, and magnesium.
These are present throughout the coal but they are
often enriched in the top layer, where they have
apparently been leached out of enclosing sediments.
12. Anomalous amounts of specific elements may be
found in beds contiguous to mineral ore bodies of
the same element. This is regularly the case for
coals having a mercury, lead, zinc or uranium con-
tent higher than the usual range, and may be equally
true for other elements including copper, tin and
arsenic.
129
-------
3.6 TRANSPORTATION METHODS AND THE COST OF DELIVERED COALS
Western coal is moved to Midwestern markets in a variety of
ways. The lack of navigable waterways near the mine sites
has spurred use of rail and other means of long range trans-
port. The primary forms of transport are:
a) Rail
1) integral trains
2) unit trains
3) common carriers
b) River and lake transport
c) Slurry pipeline and fixed tramways and conveyors
d) Truck
Since transportation costs can in some instances exceed one
half the cost of producing coal, it is important to see
where these costs originate and what characterized them.
Figure 37 shows distance isopleths from Rocky Mountain coal
areas to various consuming regions in steps of 500 miles.
Nearly 30$ of the western coal produced in 1973 was shipped
out of the coal producing regions (see Table 15). Essentially
all of this coal was shipped by some form cf rail transport.
Small quantities were shipped via the Great Lakes and rivers.
The major modes of transportation used to r.ove coal through-
out the western markets (70$ of total production) were
private railroad, truck, tramway, conveyor and slurry pipe-
line. A breakdown of western tonnage hauled by method of
movement is given in Table 31. The 1973 haul basis (59.9
MMT) differs somewhat from the 1973 production figure (58.9
MMT) given in Table 15 because of combined methods of movement
used in computing totals.
130
-------
l''ir.ure 37. Western coal distance to major markets
53
53Wasp, K. J., and T. L. Thompson. Bechtel Incorporated.
Slurry Pipelines - Energy Movers of the Future. (Presented
at the Interpipe 73 Conference. Houston, Texas. November
1, 1973- ) P. 5.
131
-------
Table 31. WESTERN COAL TONNAGE BY METHOD OP MOVEMENT*5
(thousand tons)
Haul Basis for 1973 - 59.896 x 106 Tons
Method of Movement
Rail
% Total
River and Ex-River
% Total
Great Lakes
% Total
Truck
% Total
Tramway, Conveyor,
and Private Rail-
road
% Total
Total Tonnage
% of Total
Western Use
—^— — — — — ^— — _
17924
29.9
0
0.0
0
o n
22l30a
36.9
3246a
5.4
43300
72.2
Non-Western Use
15796
26.4
681
1.2
119
0.2
0
0.0
0
0.0
16596
27.8
Total
33720
56.3
681
1.1
119
0.2
22130
36.9
3246
5.4
59896
100.0
d3ome shipments via tramway, conveyor, slurry pipeline, and
private railroad are included with the truck category.
25
PP. l-
-------
3.6.1 Rail Methods and Economics
Various rail methods are used to ship western coals to mid-
western and other non-western locations. Major rail movements
are usually made in complete trains handled as integral units.
There are three types of movements involved. The first uses
the "bulk rate" train or commercial carrier which is generally
made up of shipments from one or more points or origin and
requires a set minimum tonnage per train to qualify for
special rates.1 The "unit", train is made up for movement
between one point of origin and one destination (with the
possibility of alternating trips to other destinations to
obtain better utilization of equipment).1 The "integral"
train consists of cars and motive power coupled from origin
to destination and return (except possibly for periodic
maintenance).1
Commercial or common carrier operation is characterized by
individual coal car shipments dispatched from the regular
railroad operating pool. Costs are high since cars are
loaded or unloaded singly in small blocks as is done in
normal rail shipments. In contrast, the unit train is used
solely for the transport of coal to its market use. Delivery
of sections of the unit train to various destinations proceeds
enroute, and the cars are collected on the return trip.
Variables that determine the best economic and technological
balance of components are: minimum train tonnage, haul
distance, car type, topographical conditions, capacity,
quantity, motive power requirements, supply of railroad
cars, loading facilities, unloading facilities, and storage.1
142, 142, 142, 142.
133
-------
The integral train is even more specific in its function-
ality. This rail mode is entirely devoted to direct delivery
of coal with no alternate deliveries enroute. Moves must be
Planned carefully, since the cars remain connected The
variables influencing the successful operation of the integral
train are essentially those of unit trains. Both unit and
integral trains are often referred to as shuttle trains.
Class 1 railroads that currently handle coal throughout the
West and deliver to midwestern markets are listed in Table 32
Current freight prices for these rail systems are included
where possible. Available cost data for rail transport from
producing district to consumer state are given in Table 33
Figure 38 shows the major rail linkages between coal sources
and existing and potential markets.
The existing rail system in the West is beset with a variety
of technical problems that influence development and expan-
sion. Rail expansions from the coalfields to midwest markets
are faced with the problem of tremendously long dead head
runs back to northwestern fields. One proposed solution to
this problem is to haul non-toxic wastes westward from mid-
western metro areas.5I*
The surface mined deep pits could be filled with the refuse
which would help coal companies meet or exceed stringent
near-original contour provisions of legislation. Cities would
benefit from lessened waste disposal problems. Railroads
might also realize a profit from the long haul back. All these
concepts seem, however, far from realization and would require
an enforcing legislation to be broadly accepted.
5t*Blakely, J. w. The Western Scene. Coal MininK and
Processing. 11:43, June 1974. "ming and
134
-------
Table 32. CLASS I RAILROADS SERVING WESTERN COAL
MARKETS AND POINTS EAST1
(Costs given are dollars per ton)
ATCHISON, TOPEKA. AND SANTE PE RAILWAY CO.
Territory Served: Chicago and West, including 111., Iowa (Ft.
Madison), Mo., Kans., Colo., Okla., Tex., La.,
N.M., Ariz, and Calif.
1972 Coal Tonnage Moved: 3,751,213
BURLINGTON NORTHERN INC.
Territory Served: From Chicago, 111., across the northern and
central regions of the U.S. to Portland,
Seattle, Vancouver, B.C., including states
of 111., Ind., Ky., Mo., Kans., Iowa, Wyo.,
Wis., Minn., N.D., S.D., Mont., Idaho, Wash.,
Ore., Calif., Neb., Colo., Manitoba and British
Columbia
1972 Coal Tonnage Moved: 25,000,000 T.
Unit Train Tonnage: 15,000,000 T.
Percent of Total: 60.0$
Loading Point; Colstrip. Mont.
Cap.:10,000 T.
Destination: Hammond, Ind.
Time: 7 Days
Rate: $8.60
Loading Point: Colstrip, Mont.
Cap.: 10,000 T.
Destination: Cohasset, Me.
Time: 5 Days
Rate: $3.23
Loading Point; Colstript Mont.
Cap.: 6,bOO T.
Destination: Minneapolis, Minn,
Time: 5 Days
Rate: $4.44
Loading Point: Colstrip, Mont.
Cap.: 10,000 T.
Destination: Plaines, 111.
Time: 7 Days
Rate: $8.99
Loading Point; Zap. N.D.
Cap.: 4,000 T.
Destination: Glenharold, N.D.
Time: Daily
Rate: $.41
•Loading Point; Colstrip. Mont.
Cap.: 6,500 T.
Destination: St. Paul, Minn.
Time: 5 days
Rate: $4.69
Loading Point: Colstrip. Mont.
Cap.:10,000 T.
Destination: Havana, 111.
Time: .7 Days
Rate: $ 8.22
Loading Point; Colstrip. Mont.
Cap.:2,000 T.
Destination: Billings, Mont.
Time: 2 Days
Rate: $1.56
Loading Point: Decker. Mont.
Cap.:10,000 T.
Destination: Havana, 111.
Time: 5 days
Rate: $7.95
Loading Point; Kleenburn. Wvo
Cap.:5,000 T. —
Destination: Havana, 111.
Time: 7 Days
Rate: $7.88
1pp. 157-161.
135
-------
Table 32 (continued). CLASS I RAILROADS SERVING
WESTERN COAL MARKETS AND POINTS EAST1
(costs given are dollars per ton)
CHICAGO AND NORTHWESTERN TRANSPORTATION CO.
Territory Served: 111., Wis., Minn., Iowa, Mo., Neb
N.D., S.D., Major gateways served
E. St. Louis, Kansas City, Omaha,
Sioux City, Minneapolis, St. Paul
Superior, Milwaukee
1972 Coal Tonnage Moved: 11,858,869 T
Unit Train Tonnage: 7,976,739 T.
Percent of Total: 67.3$
« Wyo.,
Chicago,
Fremont,
Duluth-
Loading Point: Hanna, Wyo.
Cap,: 9,500 T. Min.
Destination: Sergeant Bluff, Iowa
Time: 3 Day Cycle
Rate: $2.63
Loading Point; Dana. Wyo._
Cap.: 90 Cars, 9,000 T, Min,;
100 car Max.
Destination: Waukegan, 111.
Time: 5 Day Cycle
Rate: $6.08
Loading Point: Dana. Wyo.
Cap.: 90 Cars, 9,000 T. Min.; 100 car Max.
Destination: Hammond, Ind.
Time: 5-1/2 Day Cycle
Rate: $7.07
CHICAGO, ROCK ISLAND AND PACIFIC RAILROAD CO.
Territory Served: Operates in the States of 111., Iowa, Minn
Neb., Kans., Mo., Okla., Ark., Tex., La., '*
N.M. and Colo.
1972 Coal Tonnage Moved: 2,160,356 T
Unit Train Tonnage: None, Volume Rates.
DENVER AND RIO GRANDE WESTERN RAILROAD
Territory Served: Colorado and Utah
19^2 Coal Tonnage Moved: 8,677,90^ T
Unit Train Tonnage: 5,365,088
Percent of Total: 6l.8%
Unit Train Shipments:
Loading Point: Sunnys-Mo Utah
CapTi «, 400 T.
Destination: Kaiser, Calif,
Time: 4 Days R.T.
Rate: $5.46
Loading Point; Carbondale
Cap.:3,200-6,000 T.
Destination: Geneva, Utah
Time: 12 Hrs, OW
Rate: $2.75
Loading Point; Somerset, Colo
Cap.: 3,100-4,500 T^~
Destination: Wash., Utah
Time: 12 Hrs. OW
Rate: $1.83
.Colo. Loading Point: Carbondaig
Cap.:6,400 T.
Destination: Kaiser, Calif
Time: 4 Days R.T.
Rate: $6.86
JPP. 157-161.
136
-------
Table 32 (continued). CLASS I RAILROADS SERVING
WESTERN COAL MARKETS AND POINTS EAST1
(costs given are dollars per ton)
Loading Point: Columbia. Utah Loading Point: Price. Utah
CapTi 3,100-4,500 T. Cap.: 2,500 T. !—
Destination: Wash., Utah Destination: Gadsby, Utah
Time: 10 Hrs. OW Time: 2 Days R.T.
Rate: $7-35 Rate: $2.40
Loading Point: Wash., Utah
Cap.: 2,600-3,700 T.
Destination: Geneva, Utah
Time: 4 Hrs. OW
Rate: $1.21
ELGIN, JOLIET AND EASTERN RAILWAY CO.
Territory Served: Circle Chicago outside of Switching District
beginning at Waukegan, 111., on Lake Michigan
on the North and swinging through Joliet,
111., into Gary, Ind., and South Chicago,
111., on Lake Michigan on the South.
1972 Coal Tonnage Moved: 10,282,460 T.
Unit Train Tonnage: 9>28l,083 T.
Percent of Total: 90. 3%
Loading Point: Colstrip. Mont. Loading Point: Dana, Wyo.
Cap.: 10,000 T. Min. Cap.: 9>000 T. Min.
Destination: Hammond, Ind. Destination: Hammond, Ind.
Time: 7 Days Rate: $7.07
Rate: $8.03
MISSOURI PACIFIC LINES
Territory Served: Midwest, South West and Western United States
1972 Coal Tonnage Moved: 8,945,879 T.
"Unit Train Tonnage: 6,082,640 T.
Percent of Total: 68%
NORTHWESTERN PACIFIC RAILROAD
65 Market St., San Francisco, Cal. 95105
D. K. McNear, Pres.
SOO LINE RAILROAD
Territory Served: N.D., S.D., Minn., Wis., Upper Penin. Mich.,
Northwestern 111. and Eastern Mont.
1972 Coal Tonnage Moved: 842,610 T.
Unit Train Tonnage: None
1pp. 157-161.
137
-------
Table 32 (continued). CLASS I RAILROADS SERVING
WESTERN COAL MARKETS AND POINTS EAST1
(costs given are dollars per ton)
UNION PACIFIC RAILROAD CO.
Territory Served: Serves 13 Western States extending from
Kansas City, Mo., and Council Bluffs, Iowa.
on the east to Seattle, Wash., and Los
nnf70 „ , Angeles, Calif., on the west.
1972 Coal Tonnage Moved: 7,972,314 T.
Unit Train Tonnage: N.A.
WESTERN PACIFIC RAILROAD
Territory Served: Calif., Nev., Utah
Unit Train Tonnage: None
!PP. 157-161.
138
-------
Table 33. TRANSPORTATION COST CHARACTERISTICS OF WESTERN
BITUMINOUS COAL SHIPPED TO SELECTED CONSUMERS51'26
Consumption
point"
010
060
060
060
060
060
080
080
080
080
080
080
170
270
270
270
270
270
270
290
290
290
290
290
300
380
t60
190
1(90
*90
Origin point0
(coal district)
18
18
18
18
19
19
17
17
19
17
19
17
22
22
22
22
22
22
22
22
22
22
22
22
22
21
21
16
20
16
Shipping
distance
(miles)
109
1,100
1,100
1,100
1,373
1,3*9
110
21*
2*1
22
2*1
16
1,200
800
789
789
789
789
802
218
218
218
2*3
128
23
6*
1*7
351
128
360
Minimum
trainload
tonnage
thousands)
(e)
6
-
-
6
6
_
—
10
—
-
-
10
7
10
11
11
11
7
6
6
6
6
7
-
-
-
3
3
3
Annual
tonnage
thousands)
310
500
700
-
700
-
75
1,250
_
-
-
1,000
700
*00
1,000
1,500
1,750
300
_
-
300
-
1,500
300
*50
-
1,300
1,300
350
Ownership of
ransportation
equipment3
2
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
Average
Btu
per pound
11,7*9
11,7*9
11,7*9
11.7*9
10,860
10,860
NA
NA
10,860
NA
10,860
NA
10,280
10,280
10,280
10,280
10,280
10,280
10,280
10,280
10,280
10,280
10,280
10,280
10,280
NA
NA
9,*31
12,610
9,*31
Cost,
cents per
ton-mile
2.31
.72
.62
.52
.*0
.*3
1.82
.93
1.3*
*.50
1.10
3.*3
.58
.52
.52
.*5
.*!
.39
.53
.57
.83
.95
.70
.83
3.86
1.50
1.95
.88
1.52
.77
aElectric utility company consumers represent the largest share of the data. Cement manufacturing
consumers are also represented.
bPor identification of consumption point code numbers, see below.
"Several means of collection of data were used in developing this table. Consequently, the point
from which coal was shipped is listed by the location of the tipple, the freight rate district
or the coalfield. For Identification of origin point code numbers, see Table 1*.
^Cars owned by railroad are Indicated by a "1"; "2" indicates shipper-owned railroad cars.
eUnspecified.
Code
0*0
060
080
170
270
290
300
380
160
490
State
Arizona
California
Colorado
Illinois
Minnesota
Missouri
Montana
North Dakota
South Dakota
Utah
2spp. 32-*8.
139
-------
3867- 18
Figure 38. Existing railroads in relation
to markets40
)p. 85.
140
-------
Many western railroads are outmoded and in need of substan-
tial upgrading. For example, the Burlington Northern and the
Chicago & Northwestern railway systems are but single track
lines east and west. They are in need of substantial main-
tenance-of-way work to strengthen the track for the large
number of 100+ ton cars.54
The most direct rail line from the western field to mid-
western markets is the Chicago & Northwestern which hauls
coal from the Powder River Basin in Wyoming to Chicago.
Chicago, therefore, has the most immediate access to western
coal of all midwest markets. There is some doubt as to the
universal acceptance of subbituminous coal in this city due
to various technical problems (Section 4). In contrast to
Chicago & Northwestern's one-step hauling, Burlington Northern
hauls coal from Colstrip, Montana to Minnesota, Colorado,
Illinois and indirectly to Oklahoma, Arkansas, Texas and
Louisiana.51* Burlington contemplates hauling coal to St.
Louis where it will be barged to Indiana and as far away as
Ohio and West Virginia. This can involve quadruple handling
in some cases before coal reaches its destination location.
Another major line is the Union Pacific which hauls coal from
the Hanna Basin in southern Wyoming to Illinois, Iowa, Ne-
braska, Missouri, Colorado, and California. The Santa Fe
system hauls coal from New Mexico to Arizona and California,
while the Denver & Rio Grande hauls Colorado coal into Utah.
5«»pp. 42, 43.
141
-------
Costs involved in transporting western coal by rail are
strong functions of both distance and method of rail move-
ment. Figure 39 shows a somewhat outdated (1971) but none
theless relative ranking of modes of energy transport expressed
in mills per kilowatt-hour. Compared to rail haulage by
conventional methods (denoted here by shuttle train) the
Integral train concept cuts costs by one half. m 1971 iong
haul, large tonnage integral trains moved coal for approxi-
mately /| mills per ton mile.55
A recent study by the Bureau of Mines correlating economy of
haul with type of carrier, shipment size and distance showed
that western coal shipped by rail could be competitive with
foreign residual fuel oil in selected midwestern fossil fuel
markets.26 The study clearly showed that western coal would
not be competitive in the New England and eastern seaboard
energy markets. Table 34 gives the results of this study on
a delivered cost per million Btu basis. This table shows
the best market potential based on local rail coal trans-
portation lies in the East North Central and West North
Central regions. Coal from Washington is prohibitively ex-
pensive due to long hauls. Rail costs were based on "average
practice" of the rail systems as a whole. The average
practice as defined here is a least squares calculated line
of best fit for selected transportation cost data. Selected
transportation cost data are defined as all available data
supplied by electric utilities and cement manufacturers.
An interesting comparison of low sulfur western delivered
costs to high sulfur local coal delivered costs is given in
Table 35 which shows cost penalties to be incurred if
55p. 98
26
1*12
-------
-t
OJ
200
300
400
500
600
DISTANCE, miles
700
800
1000
Figure 39. Average relative energy transportation costs55
55Evans, H. W. The Economic Future of Western Fossil Fuels
Mining Congress Journal. 57:98, February 1971-
-------
Table 34. COMPARATIVE COSTS OP SUPPLYING COAL PROM
WESTERN PRODUCING DISTRICTS AND OIL PROM EAST COAST
AND GULP COAST TO EASTERN AND
MIDWESTERN MARKETS, 1970a>26
south Atlantic
(Richmond, Va.)
Coal producer district
16 and Northern and Southern
17 Colorado (Denver)
18
19
20
21
22
23
Arizona and New Mex.
(Albuquerque, N. Mex
Wyoming (Cheyenne)
Utah (Salt Lake City)
N. and S. Dakota
(Pargo, N. Dak.)
Montana (Billings)
Washington (Seattle)
i-ost i$ per
million
Btu)
Coal Oil0
0.597
.150
.193
.657
.581
.502
.968
0.287
.287
.287
.287
.287
ooai-
oll
cost
ratio
2.080
1.568
1.718
2.289
2.035
.287 1.719
•287 3.373
caoi, nortn central
(Chicago, 111.)
Cost ($ per
million
Btu)
16 and
17
18
19
20
21
22
23
Northern and Southern
Colorado (Denver)
Arizona and New Mex.
(Albuquerque, N. Mex.
Wyoming (Cheyenne)
Utah (Salt Lake City)
N. and S. Dakota
(Pargo, N. Dak.)
Montana (Billings)
Washington (Seattle)
t-oai
0.153
.337
-315
• 530
.311
.312
.805
Oil
0.180
.180
.180
.180
.180
.180
.180
Coal-
oil
cost
ratio
0.911
.702
• 719
1.101
.717
.713
1.677
Consumer neKlon
Middle Atlantic
(New York, N.Y.)
Cost ($ per
million
Btu)
uoal oi i u
0.615
.179
.'667
.597
.510
.977
(St.
0.376
.376
• 376
.376
.376
-376
.376
North C
Louis,
Cost ($ per
million
Btu)
Coal
0.133
.313
.332
.519
.391
.138
.819
011=
0.631
.631
.631
.631
.631
.631
.631
Coal-
oil
cost
1.636
1.271
1.310
1.771
1.588
1.356
2.598
!entral
Mo. )
Coal-
oil
cost
ratio
0.686
.196
.526
.823
.621
.691
1.298
New England ' ~
(Boston, Mass. )
Cost (v per
million
Btu)
0.635
.501
.523
.683
.627
.530
.998
Uli"
0.336
.336
• 336
• 336
• 336
• 336
.336
East South
(Vicksburg,
Cost ($ per
million
Btu)
Coal
Oil?
0.508 0.181
.301
.115
.583
.537
.129
.901
.181
.181
.181
.181
.181
.181
Coal-
oil
cost
ratio
— — — —
1.890
1.191
1.557
2-033
1.866
1-577
2.970
Central
Miss.)
Coal-
oil
ratio
1.050
.628
.857
1.205
1.110
.886
1.862
Cities in parentheses represent point of origin or destination for calculation of distance.
Foreign residual oil delivered to East Coast.
Foreign residual oil delivered to Qulf Coast
26PP- 32-18.
-------
Table 35. COMPARATIVE COSTS OF SUPPLYING HIGH AND LOW SULFUR
COAL FROM SELECTED PRODUCING DISTRICTS TO SELECTED CONSUMING REGIONS, 1970a»26
Producer District
16 and Northern & Southern
17 Colorado (Denver)
18 Arizona & New Mex.
(Albuquerque, N. Mex.
19 Wyoming (Cheyenne)
20 Utah (Salt Lake City)
21 N. & S. Dakota
(Fargo, N. Dak.)
22 Montana (Billings )
23 Washington (Seattle)
East North Central"
(Chicago, 111. ")
Cost of coal
per million
Btu b
Low
sulfur
0.453
.337
)
.3^5
.530
.344
.342
.805
High
sulfur
0.312
.312
.312
.312
.312
.312
.312
Cost
dif-
fer-
ence
0.141
.025
.033
.218
.032
.038
.493
West North Central
(St. Louis, Mo. )
Cost of coal
per million
Btub
Low
sulfur
0.433
.313
.332
.519
• 394
.438
.819
• High
sulfur
0.312
.312
-.. 312
.312
.312
.312
.312
Cost
dif-
fer-
ence
0.121
.001
.020
.207
.082
.126
.507
(Vicksburs, Miss.)
per million
Btub
Low
sulfur
0.508
.304
.415
.583
.537
.429
.901
High
sulfur
0.283
.283
.283
.283
.283
.283
.283
Cost
dif-
fer-
ence
0.225
.021
.132
.300
.254
.146
.618
i •
Cost
aCities in parentheses represent point of origin or destination for calculation of distance.
in cents/million Btu's.
bLow-sulfur coal is from producer district given. High-sulfur coal given is least-cost:;*vailable
high-sulfur coal (transportation cost + P.O.B. Mine price) for each consumer region. Cost figures
are in $ per million Btu.
26,
12.
-------
western coal is utilized. The lower Btu content of these
coals combined with long hauling distances makes them attrac-
tive in selected areas only.
3.6.2 Water Transport and its Applicability
Water transportation of coal by inland river and the Great
Lakes is the least expensive way to ship coal. An indication^
of relative costs between rail hauling and water transpor-
tation, based upon data from 1963, is given in Table 36.
Table 36. AVERAGE COAL FREIGHT REVENUES
FOR RAIL AND WATER, 19635G
(mills per ton mile)
Mode Revenue
Rail 10.4
Inland rivers 3.0
Lakes/oceans <2.0
No significant amounts of coal are shipped by water within
the western states due to the lack of navigable rivers.
However, combined rail/barge and rail/Great Lakes ship
systems are expected to handle increasing loads of western
coal. The previously mentioned Burlington Northern Railroad
exchange with Missouri River carriers at St. Louis is ex-
pected to distribute western coal throughout the river system
by barge. Plans include the building of extensive loading
facilities to accommodate unit train freight with shallow
draft barges.
56Anon. Using Waterways to Ship Coal. Coal Aee 7Q-1PP
July 1974. '
146
-------
A traffic crisis adverse to the smooth growth of this western
coal exchange occurs at the central interchange of the inland
river system on the boundary of southern Illinois (Figure 4o).12
Here the Mississippi, Illinois, Ohio, Cumberland, Tennessee
and Missouri rivers converge. All six of these rivers are
navigable, and overloaded locks on the Mississippi and Ohio
rivers can back water traffic up for hundreds of miles in all
directions. Delays of 12 to 16 hours are common with the
cost for individual barges falling between $75 and $100 per
hour.12 A major factor in these delays is the inadequate
size of locks that can handle large tows of barges only by
the time-consuming process of double locking. This bottle-
neck is being alleviated by the construction of new facilities.
Completion is scheduled in about four years. Thus, western
coal deliveries by this inland system will be forestalled in
the immediate future.
The Great Lakes are forecast to play an increasingly impor-
tant role in the expansion of western coal utilization. For
example, Detroit Edison has recently negotiated a large 25-
year contract with Decker Coal Company in Montana.56 Coal
will be shipped from Montana by 10,000 ton unit trains to
the Duluth-Superior area. The coal will then be transferred
to huge 1,000-foot long by 105-foot wide ships designed to
carry 62,000 tons of coal. A sketch of the planned route
to the St. Claire Plant is shown in Figure 41. Ice control
during the winter months combined with huge storage facili-
ties will increase the yearly capacity.
12pp. 192-197, 193-
56p. 125-
147
-------
CO
MVICULf LCKTMS MO UPTNS
Of ftMTCO STITEI IRLUID MTEIVIi «0«T(1
I?N it (i «•
•MKI*aMMI •*»« '1.
•• CM* iwv -*n iwn^M « Ul
OHM VMTH, ' w SI Itota
'Li »MKJ*|(IM»
«i
" "
TUTFK TUKSraCTEO ON IHUWO WiTEIVAH OF UWTED SI4IEI
(EKLtfllVC OF «tUT URtil FDt UlEMOU TEUI WOV1
M Ml fl) M
Si «i U? »
C WtBM
I Of VUSEU CM IIUHD WiTtWATS OF NMTED ITITU
(EICLMIVE Of THE SHUT UUESj F0« TfcUSKMTlTKW OF
FKMMT U OF MCfMCI II. HM
,.:s ,.'i
v :r j tx
Figure ^40. Waterways of the United States 56
56
p.
-------
Lake
St. Claire
Figure 41. Planned Great Lakes route for Detroit-Edison55
. 127-
149
-------
3-6.3 Coal Slurry Pipeline Transport
The coal slurry pipeline is a proven transport method. The
most dramatic application is the Black Mesa pipeline in
Arizona owned by Black Mesa Pipeline, Inc., a subsidiary of
Southern Pacific Pipe Lines, Inc. This is the only operational
coal slurry line in the United States. A 50/50 water-coal
slurry travels 273 miles from the Black Mesa Field to the
Mohave Power Plant in Nevada. The route is shown in Figure
42. Figure 43 is an elevation profile map of the pumping
stations and distances. This single pipeline can haul over
5-1/2 million tons of coal a year. The system is environ-
mentally attractive because the 18 inch diameter pipeline
is buried three feet underground.
The decision to move coal by slurry was one of economics
for Black Mesa. The ultimate destination required the
addition of 150 miles of new railroad track with a total haul
of 408 miles. The slurry line cut 135 miles of this while
increasing transport reliability.
Although slurry is more technically complex than rail haul-
age methods, economy of haul is realized for large-scale
operations. The key to any successful slurry system is the
slurry preparation process. It must provide a consistent
size coal to permit a reasonable balance between pumpability
and final dewatering characteristics. If sizing is too fine,
pumpability may be good but slurry may be difficult to
dewater.58 Conversely, too large or coarse a sizing results
in a heterogeneous slurry which is easily dewatered but which
must be pumped at higher velocities to maintain a suspension.58
Costs rise in either of the above cases.
•58Cowper, N. T., T. L. Thompson, T. C. Aude, and E. J. Wasp.
Processing Steps: Keys to Successful Slurry-Pipeline Systems
Chemical Engineering. 79(3):59, 59, February 7, 1972.
150
-------
NEVADA
Figure 42. Map showing route of Black Mesa
coal slurry line57
5technology and Use of Lignite - Proceedings: Bureau of
Mines - University of North Dakota Symposium, Kube, W. R.,
and J. L. Elder, (eds.). Bismark, North Dakota, May 12-13,
1971. Bureau of Mines Information Circular. 8543. 1972.
p. 16 .
151
-------
STATION No. I
NAME Koycnto
WLEPOST 0
7
SO
100
ISO
DISTANCE, miles
200
2SO
Figure 43. Profile of Black Mesa pipeline57
57,
16.
152
-------
A workable processing plant is shown in Figure 4H. Slurries
are stored in highly agitated vessels prior to pumping. The
delivered slurry is also stored in large holding tanks where
it is continuously dewatered to 25% moisture by centrifugal
dryer. The damp coal is then sent to pulverizers where the
remaining surface moisture is removed, and the coal is burned
conventionally.
Inherent problems with conventional slurry pipelines are the
large quantity of water necessary to sustain them and the
lowering of the coal's calorific value as a result of the
water contact. The excess water not used for cooling tower
makeup and ash handling at the Mohave Plant must eventually
be evaporated to the atmosphere.57 In the arid West this is
hardly the optimal solution. Thought is being given to haul-
ing coal ash in slurry form back to the mine. This would help
fill deep strip mine pits and conserve water.
General slurry transportation costs including preparation
costs are shown in Figure 45 for various distances and
tonnage. Comparative costs with unit train and EHV (extra
high voltage) transmission are shown in Figure 46. These
costs are for solid volumes of two to six million tons per
year (1970). They include both operating and capital costs
and charges.
Coal slurry pipeline networks are envisioned to be the ulti-
mate mode of coal transport in the future as they require less
operational labor than either railroads or water transport,
making them less susceptible to labor strikes. They appear
to be economically advantageous for long distance transport
57P. 29.
153
-------
v_n
4=-
CONVEYOR SYSTEM
FROM LIVE STORAGE
1
i
?
O
iM
=
n _
1
r~ JH
S re
>0 J on J
n n
1 \
_ 3 -2 HOUR CAPACITY
COAL BINS
-3 -IMPACTOR CRUSHERS
WATER SUPPLY
~]*- 3 -ROD MILLS
> 3- SUMPS & SLURRY
If SUMP PUMPS
TV
—i
n ^_
SLURRY STORAGE TANKS 1 w
PREPARATION PLANT SLURRY
BOOSTER PUMF
3- POSITIVE DISPALCEMENT
(PISTON) SLURRY PUMPS
\
1 II
1 -I
II ' II
II It
1
II II
1 TO SLURRY PIPELINE
TWO PUMPS
NORMALLY OPERATING,
PROVIDING COAL FLOW RATE
OF 660 TONS PER HOUR
>S
CAPACITY: 2 HOURS
OPERATION:ONE TANK FILLING FROM ROD MILLS
ONETANK DISCHARGING TO PUMP STATION NO 1
ONE TANK FULL & BEING SAMPLED
ONETANK CONTAINING FINES FOR
"CAPS & CHASERS"
PUMP STATION NO. 1
wo *r « wiir»^ui\j
Figure M. Process diagram of preparation plant and one pump station (Black Mesa)"
»«<*«»*•••*»»><** Coals Strong Point. Coal Age. 76:153.
-------
CO
o
o
CC O
O I-
THROUGHPUT
Million Tons"
per year
Includes Slurry Preparation
0.1-
500
DISTANCE-MILES
1000
2000
12p. 203.
Figure 45. Coal slurry pipeline
Transportation costs (1970)12
155
-------
Transportation Distance
0
3 6 9 12 15
THROUGHPUT
MILLION TONS PER YEAR OF COAL
Figure 46. Comparison of alternate modes
of energy transportation (1970)12
12p. 202.
156
-------
and are environmentally sound. Two projects are currently
under study for the U.S. for long distance coal slurry
carriage. A 1000-mile coal slurry line connecting low sulfur
coal deposits in Colorado to the lower Mississippi valley is
planned.60 Additionally, an 800-mile pipeline is planned
to link coal producing areas of Montana, Utah, Wyoming and
Colorado to the Pacific Northwest.60 A significant difference
in the slurry medium is proposed in the 800-mile study.
Methanol will be used in place of water so that the entire
slurry can be burned.
60Anon. Coal-Slurry Pipelines - A Rapidly Growing Technique.
Coal Age. 79:96,96, July 197*».
157
-------
SECTION 4
WESTERN COAL COMBUSTION
A recent survey (1973) has estimated the number of stoker
coal-fired, industrial boilers to be 124,000.61 The pro-
portions of spreader stokers, underfeed stokers, overfeed
stokers, pulverized coal and other types of industrial coal
burning equipment of various capacities are displayed in
Table 37.
Table 37. POPULATION BREAKDOWN BY BURNER TYPE OP
COAL-FIRED INDUSTRIAL BOILERS IN SERVICE IN THE U.S. (1973)62
(percentage basis by number)
Rated Capacity Range. 103lb
Underfeed
Overfeed
Spreader
Pulverized
Other
10-16
70
10
15
-
5
100$
17-100
60
15
20
-
5
10 0%
101-250
20
10
50
15
5
100$
steam/hr
251-500
15
10
30
40
5
10052
6 Duncan, L. J., E. L. Keitz, and E. P. Krajeski. Selected
Characteristics of Hazardous Pollutant Emissions, May 1973,
The Mitre Corporation. EPA Project No. 095A. Contract
No. 68-01-0438. p. 72.
62Locklin, D. W., H. H. Krame, A. A. Putnam, et al. Design
Trends and Operating Problems in Combustion Modification
of Industrial Boilers. Environmental Protection Agency
Technology Series EPA-650/2-74-032, April 1974. p. 21.
159
-------
All of the above equipment is discussed in this section.
The fuel burning equipment, boiler, and associated auxiliary
equipment for all of these installations are described, and
the influence of fuel characteristics on equipment design Is
discussed.
Eastern, midwestern and western coals burn differently and
combustion experience using these coals is compared. Equip-
ment modifications are suggested to improve boiler operation
capacity and efficiency where problems are encountered in
converting the boiler to western coal.
4.1 COAL FIRING EQUIPMENT
4.1.1 Underfeed Stokers
4.1.1.1 Single retort stoker
Underfeed stokers of the single retort, ram-fed, side ash
discharge type are used primarily for heating and for small
industrial units of less than 30,000 Ib of steam per hour."
As shown in Figure 47, these units are fed from the hopper
by a reciprocating ram, or from a screw conveyor on the
small units, to a simple trough called the retort. The coal
moves rearward by means of small auxiliary pushers, then
upward to spread over the air-admitting tuyeres.
The single retort horizontal-type stokers are usually limited
to 25,000 to 30,000 Ib of steam per hour, with burning rates
of 425,000 Btu per sq ft of grate area per hour in furnaces
having water cooled walls.46 For refractory wall furnaces,
the maximum burning rate is limited to about 300,000 Btu
per sq ft per hour.
*»6pp. 11-5.
160
-------
Pusher Block Pusher Rod
Forced
Coal Ram
Figure 4?. Single retort, horizontal-feed,
side ash discharge underfeed stoker1*6
46,
161
-------
The burning rates of underfeed stokers are related to the
coal ash softening temperature. The burning rates for coals
having an ash softening temperature of less than 2400°F must
be reduced. Since many New Mexico and Colorado coals have
ash softening temperatures above 2400°F, these western coals
can be burned at high heat release rates per unit of furnace
volume (as shown in Table 38 ).63 However, many Montana,
Whoming and North Dakota coals have lower ash fusion tempera-
tures, and it is necessary to adjust the feed rates for these
coals to maintain a lower fuel bed temperature to prevent
clinker formation. When burning low heating value western
coal, the burning rate (pounds coal per hour) must be in-
creased to obtain the same heat release rate (Btu/hour) ex-
perienced with the eastern or midwestern coal. This, of course
means that the western coal must have suitable ignition
characteristics to permit complete combustion of the fuel.
Table 38. HEAT RELEASE RATE FOR SINGLE
RETORT UNDERFEED STOKER63
(heat release rate, Btu/hr/cu ft furnace;
13? C02 by volume in gases leaving furnace)
Ratio of area of the water-tube Ash Fusion Temperature °F
surface exposed to furnace to the '
total area of the furnace enclosure
exclusive of the grate area 2,200 2 400
0.20
0.24
0. 26
0. 3'*
20,000
40,000
45,000
45,000
40,000
50,000
50,000
50,000
63Johnson, A. J., and G. H. Auth. Fuels and Combustion
Handbook. New York, McGraw-Hill Book Company, Inc. 1951
pp. 781, 756. Copyright, 1951, by the McGraw-Hill'Book
Company, Inc. Used with permission of McGraw-Hill Book
Company.
162
-------
Single retort underfeed stokers are capable of burning caking
or moderately caking bituminous coals and certain free burn-
ing bituminous coals, and, to a lesser extent, other grades
of coal or waste fuels (such as wood refuse) in combination
with such coals. The range of agitation imparted to the
fuel bed in different stoker designs permits the use of coals
with varying degrees of caking properties. This type of
stoker is used most widely for burning eastern caking bi-
tuminous coals and those midwestern free burning bituminous
coals with ash fusion temperatures high enough for successful
utilization in the relatively thick fuel beds that characterize
underfeed firing. However, fuels ranging from lignite to
anthracite have also been burned successfully.
For satisfactory stoker operation, the correct coal particle
size must be chosen to prevent particle drifting and the low
fuel bed permeability that occurs with fuels having a large
amount of fines present. The most desirable size consists
of 1-1/4" x 3/4" nut, 3/4" x 5/16" pea, and slack (size of
coal which will pass through a 1/4" round hole screen) in
about equal proportions.63 However, bituminous coal of 1 to
1-1/2" nut and slack, which contains not more than 50% slack,
can be successfully burned.63 To permit complete combustion
of the coal and to prevent loss of fire caused by air passing
through portions of the bed where there is small resistance
to air flow, the individual coal lumps should not exceed
1-1/4", particularly when the coal has a hard mechanical
structure and cannot be easily broken up by handling. Many
friable coals in 2" or even 2-1/2" sizes may be used satis-
factorily, however, because the degradation in transit and
handling is sufficient to reduce the lumps to sizes that
burn well in this type of stoker.
63pp. 781, 781.
163
-------
The coal characteristics that influence total carbon loss,
and therefore boiler efficiency, Include rank index, ash
content, heating value, and burning rate. Table 39 give the
range of carbon losses expected for four kinds of stokers
when firing eastern, midwestern and western coals. It is
apparent from the table that low ash, low heating value coals
generally have high total carbon losses. In the side ash
discharge underfeed stoker, for example, the average Montana
and Wyoming coals have expected total carbon losses of 4.9$
and 3.8$, respectively, compared with a value of 2.0$ for
average eastern coals and a value of 2.4$ for average mid-
western coals. For coals from New Mexico and Colorado, one
can expect total carbon losses of 2.9$ and 2.7$, respectively.
The minimum expected total carbon loss at maximum continuous
rating for side ash discharge underfeed stokers is 1.5$.
4.1.1.2 Multiple retort stoker
The multiple retort inclined underfeed stoker is still used
in many plants, with relatively constant loads or light loads
of long duration. This type of stoker can be used with boiler
units up to 500,000 Ib of steam per hour at burning rates up
to 600,000 Btu per sq ft per hour.4*6 With the rear end
cleaning type multiple retort stoker shown in Figure 48, the
fuel is introduced through a coal hopper and fed to inclined
retorts and grates by means of coal rams. Dumping grates are
used for ash removal in smaller units and with low ash coals
where intermittent dumping will not interfere with the load.
With large stokers and high ash coals it is desirable to use
46p. 11-5.
164
-------
Table 39. TOTAL CARBON LOSS
State
Arizona
Colorado
Montana
New Mexico
North Dakota
Utah
Washington
Wyoming
Alabama
Indiana
Illinois
Iowa
Kansas
Kentucky
Missouri
Ohio
Oklahoma
Pennsylvania
Tennessee
West Virginia
Mln
_
1.5
1.5
-
-
1.2
-
2.6
1.7
1.8
(1.5)
(1.5)
(1.5)
1.5
-
(1.5)
1.4
-
1.5
1.5
Avg
2.4
2.1
3-4
2.1
-
2.0
1.6
2.8
(1.5)
2.0
1.9
2.1
1.9
1.5
2.1
1.7
1.6
1.6
1.5
1.5
Max
-
2.5
(<6.0)
-
-
2.2
-
3-3
2.4
2.4
3-7
2.5
(2.2)
2.3
-
2.2
2.0
2.0
1.5
1.8
Min
-
(1.0)
<1.0
-
-
(1.0)
-
(1.0)
1.1
1.0
1.8
1.2
2.6
1.0
-
1.0
1.0
1.3
1.3
1.1
Avg
1.0
1.1
1.2
1.1
1.1
1.1
1.3
(1.0)
1.2
1.0
2.4
1.2
3.4
1.1
1.0
1.1
1.0
1.6
1.5
1.3
Coal Range
Max
_
1.4
1.5
-
-
1.1
-
(1.0)
1.6
1.2
3.8
(1.4)
-
1.5
-
1.2
1.1
-
1.7
1.6
Min
_
1.8
1.8
-
-
1.6
-
3.0
(1.5)
1.9
1-7
(1.5)
-
1.5
-
1.5
1.7
-
1.6
(1.5)
Avg
2.8
2.7
(4.9)
2.9
_
2.7
2.1
3.8
2.1
2.4
1.5
(2.3)
-
2.1
2.4
2.1
1.9
2.0
1.8
2.0
Max
_
3.3
<5.0)
-
_
2.9
-
(4.8)
2.9
3.2
1.9
4.9
3.5
(3.2)
-
2.9
2.2
3.3
2.4
2.9
UF-KA
Min Avg
1.6
(1.0) (1.7)
3.0 (<5.0)
1.6
— _
(1.0) 1.4
2.3
(1.0) (1.0)
(1.0) 1.5
1.5 1.5
1.0 l.l
- (4.3)
1.5 1.6
(1.0) 1.2
1.3 1.3
1.0 1.3
1.0 1.2
2.0
2.0 2.2
(1.0) 1.5
Max
3.0
_
_
_
1.7
_
(1.4)
2.0
1.8
1.3
(4.8)
1.6
2.1
1.4
1.7
1.4
2.1
2.4
2.2
OF = overfeed traveling grate stoker
S3 = spreader stoker
UP-SA « underfeed stoker, side ash discharge
UF-RA = underfeed stoker, rear ash discharge
Values in parentheses are extrapolated values.
Grate heat release rate for: OF-400,000 Btu/hr/ft2 grate area; 33=
area; UF-SA=400,000 Btu/hr/ft2 grate area; UF-RA=400,000 Btu/hr/ft2
600,000 Btu/hr/ft2
grate area.
grate
165
-------
Tuyeres
Coal Hopper
Coal
Rams
Ash Discharge Plate
Fuel Distributors
3167 3
Figure 48. Multiple retort gravity-feed type of rear
ash discharge underfeed stoker1*6
. 11-5.
-------
rotary ash discharge in which the ash is discharged to the
ash pit through slowly revolving rolls located at the rear
of the stoker. This type of ash discharge contributes to
reduced carbon losses, better furnace condition, and higher
carbon dioxide content of the furnace gas. The continuous
ash discharge type of ash removal, which is similar to the
manual dump type but with dumping performed automatically by
continuous mechanical motion, has a slightly lower comparable
efficiency because of a small increase in ash carbon loss.
The most suitable coals for multiple retort stokers are those
which have a tendency to cake, but break into a porous fuel
bed when agitated.63 Nonagglomerating coals have a tendency
to drift to the rear of the stoker and highly caked coals do
not produce a satisfactory fuel bed contour. The use of rear
arches causes a redeposit of drifted coal to the front end
of the furnace. Such arches also provide turbulence.
Coal size specifications for multiple retort underfeed
stokers usually call for 2" nut and slack with not more than
50% of the slack passing through a 1/4" round hole screen,
and for the fuel to be delivered across the hopper without
segregation.63 Uniform graduation in coal size from lump to
slack should be provided for best results. In general, a coal
with 20 to 30% volatile matter is recommended. The use of
higher volatile coals causes a marked decrease in efficiency
because of smoke formation.
63pp. 792, 791.
167
-------
Overfire air systems are often used with multiple retort
stokers to prevent smoke at low loads or upon a sudden increase
of firing rate which causes distillation of a large quantity
of volatile gases from the coal bed. Production of relatively
high velocity overfire air through rear wall Jets has been
found to be far more effective than a large number of low
velocity openings in the furnace walls.63 Action of the Jets
Is largely one of setting up sufficient turbulence to mix the
furnace gases thoroughly enough to insure proper combustion.
Furnace gas turbulence also serves to reduce fly ash carry-over.
Since furnaces usually contain enough air for combustion, steam'
may be satisfactorily substituted for air when desirable.
Only enough overfire air or steam should be used to provide
the necessary turbulence for complete combustion. Excess
overfire air will reduce furnace temperature and boiler
efficiency.
The installation of water cooled surfaces at the stoker
sidewalls helps to minimize clinker formation when coals having
a low ash fusion temperature are burned or when furnaces having
inadequate volume are used.63 The formation of clinkers in
such furnaces results from the high temperatures caused by the
higher heat release rate per unit of furnace volume needed to
meet the load. Clinker formation is a serious cause of
grate burnout.
The total carbon loss expected for rear ash discharge under-
feed stokers is influenced by the coal's rank index, ash
content, and heating value, and the grate heat release rate.
In general, the carbon losses increase as the ash content, the
63PP. 789, 789.
168
-------
rank index, and the grate heat release rate increase, and as
the coal heating value decreases. As shown in Table 39, most
of the estimated expected carbon losses for Montana coals
(where the coal properties are within the range permitting
carbon losses to be estimated) exceed the expected carbon
losses for eastern and midwestern coals. Colorado coals are
expected to have slightly higher carbon losses than eastern
or midwestern coals. The Wyoming coals for which analyses
are available are expected to have lower total carbon losses
than eastern or midwestern coals mostly because of lower ash
contents. The minimum expected total carbon loss for rear
ash discharge underfeed stokers is 1.055
M.I.2 Overfeed Stokers
As its name implies, the overfeed stoker is fed coal from
above and onto a continuously moving grate. The terms chain
grate stoker and/or traveling grate stoker are synonymous
with the term overfeed stoker. Another class of stokers,
the spreader stokers, also employ the chain or traveling
grate concept to move the burning coal bed.
The overfeed traveling grate furnace draws coal from a stoker
hopper under a vertically adjusted grate, placed across the
width of the unit which controls the fuel bed depth. The fuel
bed is carried over the several air zones of the stoker by
"bar and key" grates or by "chain" grates. The bar and key
grate is made of relatively narrow keys or clips mounted on
bars or racks which are propelled through the furnace by chain
assemblies. In general, the clips of the chain grate form
169
-------
both the chain and the grate surface. The entire coal
feeding and burning operation takes place without any agita-
tion of the fuel bed. The features of a chain grate stoker
are illustrated in Figure 49.
Traveling grate stoker applications are best suited for
industrial and institutional power plants having steady and
sustained loads in capacities from 20,000 to 150,000 Ib of
steam per hour.6" Although some units of even greater
capacities have been built, larger capacities are rare and
not recommended.
The furnace side walls are vertical. Arches in the front
or rear walls may be used to promote fuel ignition and to
provide mixing of the combustion gases by producing turbu-
lence. Arches are necessary for burning low-volatile fuel
such as anthracite and coke breeze, or high moisture fuels
such as lignite. The use of arches causes many variations
in furnace design with chain grate and traveling grate fur-
naces .
In the absence of arches (in furnaces designed for burning
bituminous coals, for example) overfire air Jets are neces-
sary to provide turbulence and ignition. Rear Jets take the
Place of a rear arch by forcing the flame toward the front and
provide more intense radiation from the flame onto the in-
coming fuel for ignition. Front Jets reverse the flow of
gases in a horizontal direction, promoting turbulence by
an action similar to that provided by front arches.
6IfHollander, H. I. Another Look at the Traveling Grate
Stoker. University of Kentucky. (Presented at The
al °?al Conference- Lexington, Kentucky, April 1
pp. 6, 3» '
170
-------
Coal Hopper
Sittings Dump
Mechanism
Drive
Linkage
Drive
Sprocket
Sittings _
Hopper
3867-2
Return
Bend
Air Seals Air Compartments Drag Frame
Figure *19. Chain grate overfeed stoker**6
. 11-6.
171
-------
The use of water cooled walls and water cooled arches reduces
maintenance on the brickwork, and reduces slag formations in
the boiler by reducing the temperature of the furnace gases.
The traveling grate stoker is capable of burning any rank of
coal except caking bituminous if properly designed and oper-
ated. The recommended size for coals having relatively high
free swelling indices is 1-1/2" x 3/8" with uniform size
graduation.61* For friable coals the recommended sizing is
1-1/4" x 0", and for nonfriable coals 3/4" x 0" with not more
than 50% passing through a 1/4" round mesh opening.61* It is
possible to burn finer free swelling coals, even mine screen-
ings, but with an increased carbon loss. Uniform distribution
of the coal sizes across the grate assists uniform burning.
Although the recommended coal ash content on a dry basis is
between 6% and 20% ash, coals having ash contents as high as
30$ have been burned in traveling grate furnaces especially
designed for this service.61* Coals burned on a chain grate
should have an ash content of less than 15*. A low ash
fusion temperature requires a lower grate heat release rate
to prevent clinker formation.61* A traveling grate furnace
should be operated to complete combustion within about two-
thirds of the grate length. If the coal ash has a low fusion
temperature it is difficult to cool the ash sufficiently on
the remaining one-third of the grate to prevent clinker
formation. The temperatures in traveling grate or chain
grate furnaces are usually low enough that ash composition
has little effect on refractories.
6t*PP. 3, 3, 3, 6.
172
-------
The total carbon losses, as with the underfeed stoker, are
influenced by the rank index of the coal, the ash content,
the coal heating value and the grate heat release rate. The
minimum expected carbon loss at the maximum continuous rating
is 1.5$. To reduce ash pit losses and to minimize dust
entrainment, the grate heat release rates should be conser-
vative .
The total carbon losses for overfeed stokers increase as the
coal ash content decreases, the coal heating value decreases
and the grate heat release rate per unit of grate area in-
creases. The total carbon losses as a function of the rank
index of the coal are at a minimum when the rank index is
38 (Btu per lb)/($ volatile matter x 10), but the total car-
bon losses increase as the rank index increases or decreases
from this value. The total carbon losses in overfeed travel-
ing grate stokers for eastern, midwestern and western coals
are given in Table 39 which indicates that the expected
total carbon losses for Montana, Colorado and Wyoming coals
are usually higher than for eastern or midwestern coals.
The minimum expected total carbon loss for overfeed traveling
grate or chain grate furnaces is 1.5%.
The coal feed rate per foot of stoker width is a function
of the boiler capacity, the coal rank index and depends on
whether the furnace is of arch furnace design or open furnace
design. Babcock and Wilcox (1972)"6 state that for high
moisture (20$), high ash (20$) bituminous coal, the maximum
burning rate is 425,000 Btu per hour per sq ft of grate area.
The maximum burning rate of lower moisture (10$), lower ash
•*6D. 11-6.
173
-------
(8 to 12%) bituminous coal is 500,000 Btu per hour per sq
ft of grate area. Some basic design criteria at maximum
continuous rating are given in Table 40. These criteria or
guidelines provide a grate and furnace design for good
practical overall performance.
4.1.3 Spreader Stokers
The spreader stoker is mostly used in the capacity range
from 75,000 to 400,000 Ib steam per hour because it responds
rapidly to load swings and can burn a wide range of fuels.1*6
The-modern spreader stoker installation consists of feeder-
distributor units (in widths and numbers as required to
distribute the fuel uniformly over the width of the grate),
specifically designed air-metering grates, forced draft fans
for both undergrate and overfire airs dust collecting and
reinjection equipment, and combustion controls to coordinate
fuel and air supply with load demand. A traveling grate
spreader stoker is illustrated in Figure 50.
The distinguishing characteristics of spreader stokers are
that coal is injected midway into the surface rather than
dumped or pushed in as is the case with overfeed and underfeed
stokers. The spreader coal feed mechanism provides a contin-
uous, well distributed supply of fuel at a variable rate as
required by the load demand. The most common mechanism is
the overthrow rotor design, although several other types are
used, depending upon the manufacturer. As shown in Figure
51, the coal is moved from the supply hopper to the over-
throw rotor over an adjustable spill plate by means of a
reciprocating feed plate. The coal falls onto the rotor
46p. 11-2.
174
-------
Table HO. BASIC DESIGN CRITERIA
AT MAXIMUM CONTINUOUS RATING64
Ash softening temperature (reducing atmosphere) °F
Grate heat release rate - Btu Input/hour/sq ft grate area
Grate coal feed rate - pounds/hour/foot stoker width
Furnace heat liberation - Btu input/hour/cu ft furnace vol.
Flame travel - (distance from grates to furnace exit) feet
Excess air leaving furnace - percent
Undergrate air temperature - °F
Free swelling index - up thru 7 1/2
- above 7 1/2
1900
300-t25,000
See diagram A
35-10,000
Approx. 12
See diagram B
2200 & above
1)50-500,000
30-35,000
30-10
80
80
300
80
15
50 75 100 150
BOILER CAPACITY, pounds steam per hour X 1000
200
20 300 350 400 450
GRATE HEAT RELEASE, BTU per sq ft per hr X 1000
Diagram A
Diagram B
*p. 6.
175
-------
Coal Hopper
Stoker
Cham ~^^
Ash Hopper
3«67 4
Ing grate spreader stoker
with front ash discharge
. 1
176
-------
Coal Hopper
Reciprocating
Feed Plate
Ash Door
Spill Plate
Overthrow Rotor
Stoker Chain
Air Seal
Figure 51. Reciprocating-feeder distributor
and overthrow rotor for spreader stokers46
11-2.
177
-------
which is equipped with curved blades for uniform coal
distribution over the furnace area.
To comply with higher burning rates for large boilers, the
continuous ash discharge traveling grate is the preferred
grate for spreader stokers.1*6 To reduce leakage and strati-
fication of air along the front and rear furnace walls, where
it cannot efficiently take part in the combustion process,
the traveling grate spreader stoker has self-adjusting air
seals at both the front and rear of the grate. Average
burning rates of the traveling grate spreader stoker are
approximately JQ% greater than rates for stationary grate
and dumping grate designs. Other continuous cleaning grate
designs include the reciprocating and vibrating grates.
Furnaces with refractory walls are sometimes installed with
stationary or intermittent dumping grate spreader stokers,
but the maintenance costs of such refractories are high. For
traveling or continuous cleaning spreader stoker grates where
slag or clinker formation adjacent to the stoker would inter-
fere with the movement of the fuel beds, water cooled walls
are a necessity. Since arches are not desirable, the water
walls are vertical, or nearly so.
The turbulence necessary for successful suspension burning
is provided by an overfire air system with guage pressures
of 27 to 30 inches of water.1*6 The high pressure air jets
are customarily placed in two evenly spaced rows in the
furnace rear wall and in one row on the front wall.
46p. 11-2, 11-3.
178
-------
Since a part of the combustion in spreader stokers takes
place in suspension, a greater carry-over of carbon-containing
particulate matter occurs in the flue gas than with other types
of stokers.63 An increase in boiler efficiency of 2 to 3%
results from reintroducing fly carbon into the furnace.k&
The fly carbon from spreader stokers is easily collected in
a cyclone type collector. This collector is provided with a
selective feature which permits the skimming-off of the coarse
carbon-containing particles. The fines are deposited in a
hopper for discharge to the ash disposal system.
As the amount of fines in the coal increases and the size of
the fines decreases, the carbon loss out of the stack will
increase. Units with inherent fly ash traps, and equipped
with dust collectors and fly ash returns, will show less
loss from this cause than units not so equipped. Coals
having a high ash content will show an additional overall
efficiency loss. Coals having a low ash fusion temperature
will cause clinker formation* These clinkers carry away
carbon, resulting in lower boiler efficiency, and also cause
higher maintenance.
The ash is removed from stationary grates manually one sec-
tion at a time by hoe or rake. The practical maximum grate
length open to air flow for a stationary grate is 9 ft.1*-6
Intermittent dumping grate stokers discharge the ash to pits.
These pits may be shallow for firing or clean out if basement
space is not available. The length of a dump grate arranged
63P. 795.
"6pp. 11-3,
179
-------
for floor cleaning should be less than 12 ft.*6 With a
basement ash pit, the dump grate length should be less than
15 ft.
The traveling grate spreader stokers require either a base-
ment ash pit or a firing level elevation to obtain the
necessary ash storage capacity. The recommended maximum
net length for traveling grates is about 18 ft.46
For vibrating grates and reciprocating grates in spreader
stokers, the recommended maximum grate length is 15 ft.46
The conventional ash transport systems used for ash removal
from ash pits are usually pneumatic conveyors or sluices.
The minimum recommended grate heat release rate is 125,000
Btu per hr per sq ft of effective air-admitting grate area.
The maximum recommended rate for continuous ash discharge
stokers with traveling grates is 750,000 Btu/hr/sq .ft of
effective grate area, and for stationary or dumping grate
stokers it is 450,000 Btu/hr/sq ft. For continuous ash
discharge stokers with oscillating or vibrating grates, the
maximum rate should be less than 650,000 Btu/hr/sq ft of
effective grate area.
Of the stoker burners, the spreader stoker can burn the
widest range of coals. Coal ranks from lignite through semi-
anthracite (even anthracite with certain qualifications) can
be burned on a spreader stoker." Since most of the volatile
matter and tarry hydrocarbons are distilled from the coal
"6pp. 11-4, 11-4, 11-4.
63p. 795.
180
-------
particles before they reach the grates, the coal caking
properties have little effect upon spreader stoker perfor-
mance. Coals with high ash content and low ash fusion
temperature are more easily burned with spreader stokers
than with other stoker types .
The feed coal characteristics which most affect spreader
stoker performance are the coal sizing and moisture content.
Although the spreader stokers will burn fuel sizes ranging
from slack to 1-1/4" to 1-1/2" nut and slack, a considerable
range in size consist is necessary for uniform fuel distri-
bution on the grate. For example, with double screened coals
the coal has a tendency to fall on only one portion of the
grate. Coal which is too large and coarse may cause the
fuel bed to burn down unevenly, forming clinkers in the
areas containing the large sizes.63 Also, large coal lumps
falling on the grate may not be completely consumed.
The use of fuels having a high surface moisture content
causes difficulty in obtaining proper coal feeding and coal
distribution on the grates because the wet coal particles
may stick to the feeder surface and cause erratic perfor-
mance. However, this problem does not occur for coals with
high inherent moisture content, such as lignites.63 Coals
that are fine and dry tend to feed too rapidly.
4.1.4 Water Cooled Vibrating Grate Stokers
Introduced to the American market in the 1950's, this type
of stoker is an adaptation of a European design used success-
fully with many low ranking lignite and brown coals found in
63pp. 798,799.
181
-------
central Europe. It is also capable of burning better grades
of coal. Because of simplicity, inherent low fly ash carry-
over characteristics, and very low maintenance, this stoker
has been steadily gaining acceptance and now has replaced
larger size multiple retort underfeed stokers in the inter-
mediate range.1*6
Since the water cooled vibrating grate stoker is capable of
burning a wide range of coals, even coals having a high free
swelling index can be successfully burned in a porous bed
without formation of large clinkers because of the gentle
agitation provided by the vibrating grate.
As shown in Figure 52, this type of stoker consists of a
tuyere grate surface mounted on a grid of water tubes that
are interconnected with the boiler water system for positive
cooling. A number of flexure plates support the entire
structure, permitting the grid and its grate to move freely
in a vibrating action that conveys the coal from the feed
hopper onto the grate and finally to the rear of the stoker.
The ashes are automatically discharged from the end of the
grate to either a shallow or besement ash pit. The grates
vibrate intermittently, with the vibration frequency regulated
by a timing mechanism.46
Slag formation next to the stoker is prevented by the use
of water cooled walls. Turbulence and ignition are promoted
by the use of a rear arch which extends over about one-third
of the fuel bed. A short front arch is added for bituminous
1+6
PP. 11-5, 11-6.
182
-------
Grate
Tuyere
Blocks
OverfireAir Coal
Hopper
Coal
Gate
3867.5 Air Control Dampers Flexing Plates Vibration Generator
Figure 52. Water cooled vibrating grate stoker46
. 11-5.
183
-------
coal. Combustion is promoted by the use of high pressure
air Jets located in the front arch. With low-volatile fuels
a refractory facing over the water cooled front arch may be
necessary to promote ignition.
Although burning rates vary with different fuels, the maxi-
mum heat release rates should not exceed 400,000 Btu per
hour per sq ft of grate area.46 If the burning rate is held
below this value, fly carbon losses are held to a minimum.
4.1.5 Pulverized Coal Furnaces
Because of the capital costs required for small pulverized
coal installations, in comparison with similar size stoker
installations, pulverized coal units smaller than 100,000
pounds steam per hour are uneconomical.1*6 In larger units
where the furnace size and configuration are less dispro-
portioned, lower operating costs result from greater
efficiency. The furnace must be proportioned so that com-
bustion is completed within the furnace volume for the type
of firing used. For pulverized coal furnaces the heat
release range is usually between 15,000 and 22,000 Btu per
hour per cu ft of furnace volume.
A pulverized coal system consists of: a pulverizer, where
the coal size is reduced to the required fineness; a burner,
in which the pulverized coal-primary air mixture is mixed
with the proper amount of secondary air and delivered to
the furnace for combustion; a coal feeder that controls the
rate of coal feed to each burner; coal and air conveying
1*6
pp. 11-6, 9-1.
-------
lines; and fans that supply air to the pulverizer and de-
liver the coal-air mixture to the burners. The primary
coal characteristics that influence the design of pulverized
coal firing equipment are Hardgrove grindability, coal rank,
coal moisture content, coal volatile matter content, and coal
ash content. The usual limits in these coal characteristics
for pulverized coal firing are: (1) maximum total moisture
(as fired), 155? (although higher inherent-moisture-content
coal such as bituminous or lignite may be used); (2) minimum
volatile matter (dry basis), 15/2; and (3) maximum total ash
(dry basis), 20$.46
A pulverizer should have a rapid response to load change
and be capable of a long period of continuous operation. It
should maintain prescribed performance throughout the life
of the pulverizer grinding elements, be able to operate
with a wide range of coals, be easy to maintain, and occupy
a minimum of building volume. Coal pulverizers are avail-
able in capacities up to 60 tons per hour.1*6
The most important factors in the selection of pulverizers
are the Hardgrove grindability index and the quantity of
the coal to be processed.46 In pulverized coal-fired boilers,
the pulverizer itself is a limiting factor with respect to
boiler capacity. Since boiler output is approximatley pro-
portional to the coal heating value, boiler capacity will
be reduced when a low heating value western coal is used in
a pulverized coal combustion system designed for high heating
value eastern and midwestern coals. The relative hardness
of a coal is shown by its Hardgrove grindability index; the
higher the index, the more easily the coal is pulverized. The
*6pp. 9-8, 9-6, 9-8.
185
-------
capacity of a pulverizer is therefore greater for a coal
with a higher grindability index. From available Hardgrove
grindability values summarized in Table 4l it can be seen
that western coals have lower grindability indices than most
eastern and midwestern coals.
The moisture content of a coal in a pulverizer should be
low enough to prevent the coal from caking on the pulverizer
liners and grinding element, permitting free flow of the coal
through the machine. In applications where a low heating
value, high moisture content coal is burned in a furnace
designed for a higher rank coal, larger motors have been
required to prevent pulverizer stall'ing caused by the increased
quantity of less free flowing coal. The coal can be dried
in its passage through the pulverizer by the use of a pre-
heated air. The maximum mill outlet temperature is deter-
mined by the coal rank. The prevalent pulverizer exit
primary air-fuel temperatures are given in Table 42. The
temperature of the primary air entering the pulverizer may
be 650°F or more, depending upon the amount of surface
moisture on the coal and the type of pulverizer.1*6 The
pulverizer wear is influenced by the coal ash content and
the silica content of the ash. The higher these quantities
are, the more often the abradable mechanical components
(such as the ball and race or roll and race) must be re-
placed.
*6P. 9-9.
186
-------
Table 4l. HARDGROVE GRINDABILITY INDEX RANGE OF COALS4 7>1*8
State
Alabama
Illinois
Indiana
Iowa
Kansas
Kentucky
Montana
New Mexico
Ohio
Pennsylvania
Tennessee
Utah
Washington
West Virginia
Wyoming
Western Average
Non-Western Average
Minimum
39
46
52
62
50
31
47
29
47
51
30
43
26
31
41
37
44
Maximum
87
75
68
66
61
75
56
43
67
117
104
50
105
108
76
66
83
1*8
pp. 1-133
187
-------
Table 42. PREVALENT PULVERIZER EXIT
PRIMARY AIR-FUEL TEMPERATURES46
Fuel
Lignite
High-volatile bituminous
Low-volatile bituminous
Anthracite
Petroleum coke
Exit Temperature, °F
120-110
150
150-175
200
200-250
Burner performance should be expected to meet the following
requirements:46 (1) the feed rate of coal and air should
comply with the load demand over a predetermined operating
range; (2) unburned combustible loss should be less than
2%> (3) the burner should not require adjustments to main-
tain flame shape; (^1) only minor maintenance should be
required; and (5) the burner should operate safely under
all conditions.
The burners used most frequently are the circular burner
and the cell burner which have maximum capacities of
165,000,000 and 495,000,000 Btu per hour, respectively.46
These burners each have a central impeller, located at the
burner's center, which promotes mixing of the fuel and the
secondary air. The turbulence necessary to mix the fuel and
air and produce short, compact flames is produced by register
doors that introduce secondary air tangentially around the
flame. The cell burner differs from the circular burner by
having several gas "spuds". These are gas pipes with multi-
46pp. 9-8, 9-11, 9-11.
188
-------
pie holes at the end to discharge gas for ignition at the
burner throat, located in a circle surrounding the impeller.
Each spud has a circular flame holder to stabilize ignition
at low inputs.
Although either burner type can be equipped to fire any
combination of the three principal fuels, combined pulver-
ized coal-oil firing should be restricted to short periods
to prevent possible coke formation on the pulverized coal
element.
Burner effectiveness is judged by: (1) compliance of full
fuel and air feed rate to boiler load demand over a pre-
determined operating range; (2) combustion process efficiency;
(3) physical size and complexity of the furnace and burners
in comparison with the limitations of space, weight, and
flexibility imposed by the service conditions; (4) ability
of the burner to meet accepted maintenance standards; and (5)
ability of the burner to operate safely under all operating
conditions.
It is necessary to provide auxiliary igniters for starting
up the burner or for maintaining the flame of a burner being
fired with moist or low volatile coal. For most coals, it
is possible to maintain ignition without an auxiliary igniter
down to one-third capacity in the boiler. It may be neces-
sary to use the igniters when burning a coal having less
than 25% volatile content even at high boiler loads.46
It is important that the igniter be activated when ignition
is momentarily lost to prevent explosive reignition from an
adjacent burner.
*6p. 9-12.
189
-------
*.2 COAL BURNING EQUIPMENT SELECTION GUIDELINES
Roberson summarized the operating characteristics of
stokers and pulverized coal burning equipment.65 His data
are presented in Table 1,3. The editors of Power magazine
recently compiled a comparison of the attributes for three
widely used stoker types, namely the spreader stoker;chain
and traveling grate stokers; and the underfeed stoker 66
The traveling grate type stokers were preferred over the
agitating grate type for all three stoker types The
comparison data for all three stoker types compared are
shown in Table W. Excpet for the inability to maintain
smokeless combustion at all loads and the high flyash
discharge, the spreader stoker appears to be the most
favorable to operate.
1.3 BOILERS
Steel boilers are usually categorized as fire-tube type
and water-tube type. The boiler types are described below
with a discussion of their utilization, capacities, design'
characteristics, firing raethods, fuels used, and influence
of fuel characteristics on boiler design and operation.
The proportions of the various industrial boiler types in
capacity ranges of 10,000-16,000, 17,000-100,000 and 101
000-250,000 pounds stean, per hour are given in Table 45
-1 •-
190
-------
Table 43- COAL BURNING EQUIPMENT
OPERATING CHARACTERISTICS65
Pulverized
1. Load range la wide and varies with the number and type of
pulverizers.
2. Flyash carry-over In the flue gases Is high, and It Is finer than
the flyash from the spreader stokers. Therefore, although the boiler
must be designed to prevent erosion, the allowable flue gas velocity
is somewhat higher.
3. Initial cost for pulverized coal equipment Is about the same as for
spreader stokers at 250,000 Ib/hr. It becomes less expensive above
these capacities.
1. Pulverized coal equipment can burn a very wide range of coal.
5. Maintenance costs for pulverizers vary considerably with types of coal.
6. Response to load changes is very fast.
7. Coal sizing to a pulverizer Is 3/1 in. x 0. Coal segregation Is
no problem.
8. Repairs and maintenance on pulverizers may be conducted while the
boiler Is in operation by taking one of several pulverizers out of
service at a time.
Vibrating Orate stoker
1. A wide load range-form banked fire to maximum capacity.
2. Low flyash carry-over unless the unit Is overloaded.
3. A dust collector may be required, depending upon local conditions.
1. Sizing and distribution of coal Is Important.
5. Caking coals have been burned on this stoker.
6. Water-cooled grates tend to reduce grate maintenance when
properly designed.
7. Burning rate is usually about 100,000 Btu/sq ft-hr with a furnace
heat release of 30,000 Btu/cu ft.
Chain and Traveling Orate stoker
1. Wide load range from banked fire to maximum capacity.
2. Low flyash carryover In the flue gases; a dust collector is not
usually required.
3. Initial cost Is more than for an underfeed stoker.
II. Ash softening temperature should be reasonably high, about 2200°P
or higher.
5. Maintenance costs are generally low.
6. Response to load changes Is about medium, faster than the underfeed
but slower than the spreader.
7. Coal sizing should be 1 In. x 0 with approximately 20* to 50« through
a 1/1 In. screen.
8. Coal should have a minimum ash content of 6* on a dry basis to
protect the grates from overheating.
9. Sensitive to changes in coal sizing and distribution.
10. Offered for a maximum continuous burning rate of 125,000 Btu/sq
ft-hr with high moisture (20*), high ash (201) bituminous coals,
such as that from some districts in Illinois, and 500,000 Btu/sq
ft-hr with lower moisture (10»), lower ash (8-12J) bituminous coal,
such as that from Kentucky. Furnace heat release should be a
maximum of 30,000 Btu/cu ft for water-copied furnaces.
11 Large (above 70,000 Ib/hr) front arch, chain grate stokers should
havf a maximum heat release of about f MKB/ft (MKB - million Btu)
of stoker width for Kentucky coal, depending upon the volatile
matter and-heating value.
12. Strongly coking coals are not suitable for conventional chain or
traveling grate stokers.
191
-------
Table 43 (continued). COAL BURNING EQUIPMENT
OPERATING CHARACTERISTICS65
Underfeed Stoker
1. A wide load range banked fire to maximum capacity.
2. Low flyash carryover with the flue gases, provided the stoker 13
not overloaded.
3- Initial cost Is low compared to other stokers.
1. Ash softening temperature should be 2500"? or above for beet oper-
ation. Coals with ash softening temperature of 2!00°t> to 2500°P
may be utilized; however, the heat release r«te per square root of
grate area must be reduced about 20%.
5. In general, maintenance costs are higher than for other stokers.
6. Response to load changes la rather alow, because of the relatively
large fuel bed.
7. Coal sizing should be 1-1/1 In. x 0, nut and slack, with not more
than 50* through 1/1 In. screen to obtain proper distribution on
the grate.
8. The free swelling Index should be below about seven to maintain
proper fuel distribution In the furnace and to keep maintenance
to a minimum.
9. Orate heat-release rate should be no more than 125,000 Btu/sq ft
and a maximum furance heat release rate of 35,000 Btu/cu ft for
water-cooled furnaces.
Spreader Stoker
1. Turn down or load range Is generally from 1/5 load to maximum
capacity. With additional equipment, minimum load can be decreased
to about 1/8 of maximum load.
2. Since about 25J of the coal burns In suspension, the flyash carry-
over Is high. A dust collector Is always required. A preclpltator
may be required depending upon the air emission regulations.
3. To obtain the best reasonable efficiency, the flyash collected In
the boiler hoppers must be relnjected onto the atoker grate.
1. Initial cost of a dumping grate spreader stoker Is the lowest, with
the pulsating or oscillating grate next, and the traveling grate the
highest.
5. The spreader will burn with little difficulty a wide variety of coals
or different fusion temperatures and different coking Indices.
6. In general, maintenance costs are approximately the same as for
a chain grate.
7. The spreader stoker has a very fast response to load svlngs.
8. Coal sizing should be 3/1 In. x 0 with no more than 50« through a
1/1 In. mesh. The pulsating or oscillating grates should be fired
with coal having an ash softening temperature of above 2200°P to
ensure proper coal and ash flow over the grates.
9. Spreaders are designed for burning rates from 450,000 Btu/sq ft-hr
for dumping grates to 600,000 Btu/sq ft-hr for pulsating or oscilla-
ting grates, to 750,000 Btu/sq ft-hr for traveling grates. Furnace
heat release should be a maximum of 30,000 Btu/cu ft.
10. On large spreaders (above 70,000 Ib/hr steam capacity) the heat
release per foot of stoker width must also be considered, and will
vary from about 8 MKB/ft-hr to 13 MKB/ft-hr depending upon the amount
and method of flyash relnjectlon.
11. Some mention should be made of th* two types of relnjectlon generally
used: pneumatic and gravity types. The gravity type is much pre-
lerred for the higher steam capacities, (above 70,000 Ib/hr) If
equipment arrangement and building space Is sufficient. As the name
Implies, the flyash flows by gravity from the boiler hopper and Is
deposited on the stoker grates. The stoker should be lengthened
to accommodate this gravity return.
65pp
192
-------
Table 44. STOKER EQUIPMENT COMPARISONS66
Unit has the ability to:
Increase load rapidly
Minimize carbon loss
Overcome coal segregation
Accept a wide variety
of coals
Burn extremely fine coal
Permit smokeless combus-
tion at all loads
Minimize flyash discharge
to stack
Maintain steam load under
poor operating conditions
Minimize maintenance
Minimize power consumption
(stoker and boiler
auxiliaries)
Handle ash and cinders
easily
Spreader
Excellent
• Pair
Fair
a
Poor
Poor
Poor
Good
Good
Good
Excellent
Chain and
Traveling
Grate
Pair
Pair
Poor
Poor -
Poor
Good
Good
Poor
Good
Good
Good
Underfeed
Pair
Pair
Poor
Poor
Poor
Good
Good
Poor
Fair
Good
Fair
^Traveling grate type is rated excellent, agitating type
is rated fair
66p.s_30. Reprinted with permission from POWER, March 1974
193
-------
Table 45. POPULATION BREAKDOWN BY BOILER TYPES67
(percentage basis by number)
Rated capacity range
103 Ib steam/hr
Water-tube boilers
Packaged
Field erected
Fire-tube boilers
Packaged Scotch
Firebox
Horizontal return tubular
Misc. (locomotive type,
etc. )
Total
• 10-16
15
7
30
25
20
3
100%
17-100
55
24
10
10
1
nil
1005?
101-250
25
75
—
—
—
—
100#
4.3.1 Fire-Tube Boilers
Fire-tube boilers are used for heating systems, for indus-
trial process steam, or as portable or mobile boilers.
They are built with capacities up to about 22,000 Ib steam
per hour. The low pressure heating boiler is limited to
15 psig steam pressure and the power boiler to 400 psig
steam pressure.
G7Barrett, R. E., S. E. Miller and D. W. Locklin. Field
Investigation of Emissions from Combustion Equipment for
Space Heating. Battelle Columbus Laboratories, EPA
Contract No. 68-02-0251. June 1973- p. 8.
-------
The fire-tube boiler consists of an external or an in-
ternal furnace where the fuel is burned, and a number of
water-surrounded tubes through which the combustion gases
pass. An external furnace has walls made up of refractories,
and an internal furnace is surrounded by water walls.
The horizontal return tubular fire-tube boiler has been
used for industrial processing applications in small in-
dustrial plants and for heating large buildings. As shown
in Figure 53, the boiler consists of a cylindrical shell
with flat ending closures, between which are supported a
large number of horizontal fire tubes. The fuel is burned
in an external furnace beneath the front portion of the
shell. The hot combustion gases from the furnace rise to
the bottom of the shell, pass over a bridge wall and sweep
over the shell to the rear of the installation. The hot
gases then enter the horizontal tubes and return to the
front of the boiler before being discharged. The water
circulates down the shell walls, then up past the tubes.
The boiler has a large capacity and a large steam release
surface.
The short firebox boiler shown in Figure 54 is a horizontal,
two-pass fire-tube boiler. The furnace, located beneath
the front portion of the shell, may have front, side, and
lower rear walls made of refractories, or it may be of the
water-leg type. The upper rear wall of the furnace is formed
by the front tube sheet of the first tube pass. The second
tube pass is located above the first and ends over the furnace,
The gases from the furnace immediately enter the first
tube pass, travel through the rear smoke box, reverse direc-
tion and travel through the second tube pass, and then are
discharged. The boiler has a large water capacity and an
adequate heat release surface.
195
-------
cn
:SECOND PASS:
FIRST PASS
A
Figure 53. Horizontal return tubular boiler
68
G8Shields, C.D. Boilers - Types, Characteristics, and
Functions. New York. P. W. Dodge Corporation. 1971. p. 19•
-------
_J
SECOND PASS
FIRST PASS
Figure 54. Short firebox boiler68
68p. 22.
-------
The compact boiler shown in Figure 55 has a horizontal
fire-tube boiler consisting of a shell with two passes of
tube attached to tube sheets inside the end enclosures. The
furnace, located under the front portion of the shell, may
be of the external or internal type. The hot gases from the
furnace pass over the lower half of the shell, travel to
the rear of the boiler where they turn, and travel through
the first tube pass to the front smoke box, reverse direction
pass through the second tube pass and then are discharged.
Boilers with internal furnaces have good water circulation
and steaming characteristics. The external furnace boiler
has sluggish water circulation and steaming characteristics.
The compact fire-tube boiler has higher efficiency than
other types of fire-tube boilers.
The Scotch boiler, shown in Figure 56, consists of a cylin-
drical shell with one or more cylindrical internal furnaces
built into the lower portion of the boiler and one or more
tube passes attached to the tube sheets placed at the rear
combustion chamber and front smoke box. The furnace itself
is a large-diameter tube which is not normally refractory
lined, but usually has flame shaped throat refractory at the
oil or gas burner location. Since it is not possible to
alter the furnace size, a Dutch oven is installed when it
becomes necessary to increase the furnace volume. A Dutch
oven is simply a burning chamber lined with water cooled
brick and a stationary grate.68 The combustion gases flow
through the furnace to the combustion chamber, then enter
the tube pass (or passes) and are discharged. Small capacity
Scotch boilers have adequate water circulation, but water
circulation in large units is sluggish, especially at start-
•
68p. 122.
198
-------
vo
Figure 55. The compact boiler68
68
p. 23-
-------
IV)
o
o
Figure 56. Coal-fired Scotch boiler68
68
-------
Although fire-tube boilers are usually fuel oil or gas fired,
it is technologically possible to convert them to coal
firing if sufficient volume is available for installation of
the coal burning equipment and ash handling equipment.
However, the cost of converting a fire-tube boiler to coal
firing may be unsuitable, especially in small boilers.
4.3.2 Water-Tube Boilers
Because the utility of steel fire-tube boilers becomes
limited as capacity and pressure requirements increase,
water-tube boilers are usually used for pressures above
150 psi and capacities above 15,000 Ib steam per hour.
The steel water-tube boilers are of the horizontal straight-
tube type or bent-tube type.
Until the development of the bent-tube type of water-tube
boiler, the horizontal straight-tube boiler was used for
the majority of industrial applications. As illustrated
in Figure 57, the straight-tube boiler is made up of banks
of tubes connected to headers. These tubes are inclined to
promote circulation. A drum, arranged either horizontally
or crossways with respect to the tube axes, is connected to
the headers by circulation tubes.
Because it offers (1) greater economics in fabrication and
operation through the use of welding, improved steels and
waterwall construction, (2) greater accessibility for in-
spection, cleaning, and maintenance, and (3) the ability
to operate at higher steaming rates and deliver drier steam,
the bent-tube boiler has replaced the horizontal straight-
tube boiler in modern boiler designs. The main elements of
201
-------
STIAM SOOT BLOWER SAFETY-VALVE
OUTLET CONNECTION CONNECTION
Figure 57. Horizontal straight-tube boiler68
68
P. 33.
202
-------
the bent-tube boiler are drums connected by bent tubes.
In water cooled furnace designs, bent tubes are arranged
to form the furance enclosure, making It Integral with the
boiler. The bent-tube boiler permits great flexibility in
In design arid permits free expansion and contraction. Three
Babcock and Wilcox bent-tube boiler designs with a descrip-
tion of the capacities, steam temperatures, and pressures,
fuels used and dimensions are shown in Figures 58 through 60.
14.3.3 Fouling Characteristics
In large water-tube boiler units, slagging is a major
problem. The Bureau of Mines has conducted studies in a
pilot plant test furnace to determine the relative fouling
potentials of various coals.70 The original program objec-
tive for these studies was to develop a correlation between
the individual ash constituents and the rate of fouling in
a test furnace, but it was difficult to determine the effect
of small changes in ash composition because reproducible
results were hard to obtain. The relative fouling poten-
tials of coals having a wide range of moisture content,
ash content, sulfur content, ash fusion temperature, and
ash analysis were determined. The coal characteristics and
fouling potentials are reproduced in Table ^6.
70Technology and Use of Lignite. Proceedings: Bureau of
Mines; University of North Dakota Symposium. Elder, J. L.
and W. R. Kube (ed). Grand Porks, North Dakota, May 1-2,
1969. Bureau of Mines Information Circular. 8^71. 1970.
pp. 69-88.
203
-------
Table 46. SUMMARY DATA PROM ASH FOULING TESTS70
ro
o
-Cr
Sample*
Baukol-No
BN-1
BN-3
BN-U
Baukol-No
C-l
Beulah Mil
B-l
B-2
B-HL
B-STD
Peerless 1
0-1
Glenharolc
OH-1
OH-2
OH-3
SH-rth Dakot*
41.41
41.40
41-95
lorth Dakot
45.68
kota
43.24
39.63
41.81
11.55
Dakota
42.70
h Dakota
44.23
44.31
43-69
43-51
44.28
County, North Dakota
27
41.10
North Dakota
32
29
31
34
41.72
38.37
40.96
42.18
e, Rlchland County, Montana
I
53.9
54.9
Pike County, Alabama
ALA-1
Rockdale,
TKX-1
1
Texas
2
Malokoff, Tezaa
TEI-2
2
48.6
59.2
49.9
34
30
43
28
32
40.98
42.18
42.11
»4.23
44.88
Plied
carbon,
percent
i
43.37
48.83
49.09
a
46.52
44.71
48.57
17-75
47.71
44.92
47.34
46.84
44.99
47.66
46.67
47.19
51.27
50.22
50.18
49-51
47.26
44.03
42.40
37.85
47.10
Ash,
percent
10.22
9.77
8.97
7.81
12.05
11.80
10.44
10.73
12.38
8.34
8.85
11.33
8.83
8.64
11.71
7.01
11.41
8.85
8.32
11.77
13.78
15.48
17.92
a. 02
Sul-
fur,
per-
cent
0.51
0.54
0.53
0.85
1.82
1.31
1.35
1.03
1.47
0.94
0.68
0.86
0.90
0.74
1.37
0.30
0.29
0.33
0.36
1.04
0.80
4.01
1.86
0.75
Heating
value
Btu/lb
10,840
11,120
10,990
10,950
10,360
10,490
10,760
10,550
10,570
11,000
10,820
10,530
11,090
10,830
10,790
10,780
10,100
10,580
10,870
10,230
10,230
10,130
10,540
11,340
Ash fusibility,
~Tf | 5f— ] Pf~
Llgnlt
2,045
2,110
2,120
2,415
2,235
2,085
2,250
2,220
2,240
2,220
2,210
2,115
2,140
2,055
2,095
2,540
2,340
2,455
2,425
2,250
2,050
2,250
2,070
2,095
e
2,085
2,160
?,165
2,455
2,285
2,130
2,310
2,270
2,280
2,260
2,240
2,145
2,190
2,110
2,140
2,580
2,385
2,490
2,470
2,300
2,100
2,300
2,120
2,145
2,130
2,205
2,210
2,495
2,340
3,180
2,360
2,315
2,325
2,295
2,270
2,175
2,280
2,160
2,185
2,615
2,424
2.525
2,515
2,350
2,150
2,350
2,170
2,195
SlO, —
27.2
32.0
29.3
18.3
17.9
19.9
17.8
20.2
24.6
16.1
21.6
35.1
17.2
27.1
19.8
13.4
33.1
22.3
24.4
21.3
35-7
27.6
39-3
25.5
14.7
16.4
14.7
11.3
12.8
9.8
11.5
11.3
13.4
8.8
9.7
12.1
8.0
11.6
11.6
7.9
14.3
10.1
11.1
13.0
20.3
20.7
17.8
14.3
5.7
6.2
7.0
11.1
15.8
9.3
9.6
9-8
7.0
12.2
9.0
7.2
11.0
5.1
9.0
6.7
4.0
6.6
6.3
10.0
5.3
4.3
7-3
11-9
Coal ash analysis,
percent
0.4
0.4
0.4
0.3
0.1
0.4
0.4
0.4
0.4
0.4
0.3
0.5
0.3
0.4
0.3
0.2
0.5
0.4
0.4
O.J
0.6
0.4
1.4
1.0
0.3
0.3
0.3
0.3
0.1
0.3
0.4
0.5
0.3
0.1
0.1
0.1
0.2
0.2
0.8
0.2
0.1
0.4
0.2
0.8
0.6
0.1
0.2
0.1
17.3
19-3
20.3
27.9
20.9
19.0
22.4
21.8
21.7
22.3
25-3
17.0
24.0
21.6
22.6
39.2
32.2
39.2
32.9
22.7
16.4
12.2
16.3
20.7
MgO
1.3
5-3
5.1
8.9
5.3
5-6
7.0
8.0
8.4
5.5
6.1
4.5
6.0
6.2
6.2
10.4
6.2
9.5
8.0
9.3
7.0
10.1
1.7
6.2
Na20
17.6
7.9
8.5
1.9
1.1
9.4
5.1
6.3
3.2
9.6
9.9
6.9
11.5
9.3
7.6
7.8
2.8
1.4
4.0
0.4
0.4
0.3
0.2
0.8
K20
0.4
0.3
0.5
0-3
0.2
0.4
0.4
0-3
0.3
0.5
0.6
1.0
0.5
o 8
0.3
0.4
0.2
0.3
0-5
0.3
0.9
0.1
0.1
0.2
SO 3
12.2
11.9
14.1
19.8
25.5
24.8
25.5
21.4
23. 7
24.5
18.2
15.6
21.3
17 8
21.9
13.8
6.5
9.8
12.2
21.9
12.8
24.2
15.6
19-2
Rela-
tive
fouling
poten-
tial0
Medium
Medium
High
Low"
Low
High
Medium
High
Medium
Medium
High
N
High
Low
Medium
Low
Low
Low
Low
Low
Medium
Low
-------
Table 46 (continued). SUMMARY DATA FROM ASH FOULING TESTS70
ru
o
Sample5
Centralia,
CEN-1
Colstrlp,
CS-1
Glenrock,
QR-1
Mine No. 1
ILL-1
River Kins
ILL-2
Sunnyslde
SS-1
Arkwrlght
ARK-1
No.
of
tests
Washl
3
Rosebu
2
Wyomir
2
0, Chr
2
; Nine,
2
Mine,
2
Mine,
1
Dry
coal
rate,
Ib/hr
ngton
51.6
d County,
14. ll
g
19.2
istlan C(
H6.3
St. Cla:
51.2
Carbon Cc
41.4
Monongall
37.0
Moisture
content
as-fired,
percent
17
Montana
21
22
unty, Illln
12
r County, I
8
unty, Utah
11
a County, U
1
c
Vola-
tile
matter,
41.69
39.86
45.13
ols
39.73
lllnols
37.05
39.90
est Vlrglr
38.24
oal analys
Plied
carbon,
45.69
50.40
44.59
43.74
42.55
54.06
la
51.83
13. dry bi
Ash,
12.61
9.74
9-98
16.53
20.41
6.05
6.93
sis
Sul-
fur,
per-
0.57
0.84
0.82
4.99
5.32
0.74
2.13
Heating
value
Ash fusibility,
0FS
Subbltumlnous Coal
11,240
11,620
11.110
Bit
11,510
11,130
13,860
14,020
2,250
2,190
2,120
jmlnous
1,905
1,965
2,445
2,140
2,300
2,220
2,155
Coal
1,945
2.030
2,500
2,190
2,350
2,250
2,190
1,985
2,100
2,555
2.270
S102
46.2
35.4 '
30.5
43.7
47-6
59.2
44.8
A1,O,
25.7
19.0
15-7
17.0
17-6
24.6
29-4
Coal a
Pe,0, |T102
6.1
5-6
6.6
1
21.3
19.2
4.5
15.1
3.7
0.8
0.6
0.5
0.9
1.1
0.5
sh ana!
P205
'1.3
0.3
0.4
0.3
0.4
1.7
0.3
ysis,
CaO "
9.6
17-8
25-5
7.0
6.1
4.6
4.2
MgO | Na20 1 K20 1 SO,
1.5
4.4
3-7
1.0
2.2
0.4
1.0
0.5
0.3
0.3
1.5
0.5
1.1
0.8
0.2
0.1
0.5
1.4
1.6
0.3
0.5
5.2
16.3
16.4
6.1
3.8
2.5
3.7
tlve
foulln
poten-
tial0
(d)
Low
Low
Medlui
Low
Low
Low
aSpot samples, not necessarily representative of mine.
"Standard Method of. Test for Fusibility of Coal and Coke Ash, ASTM Designation D 1857-68. Initial
deformation temperature-IT, Softening temperature-ST, Fluid temperature-FT. ASTM Standards Gaseous
Fuels; Coal and Coke, Part 19, March 1969, American Society for Testing and Materials. Philadelphia,
Pa., pp. 331-336.
cBased on weight of deposit collected on probe bank 1 during standard test:
Welpht. grams Rating
0-150 Low
150-300 Medium
Above 300 High
dDurlng test ash built on refractory duct walls and eventually bridged across tubes. Ash did not
appear to bond much to the metal tubes.
7°pp. 76-77.
-------
Table H7. TYPICAL ASH COMPOSITION"
(wt-jB)
% of Moisture 3 of Moist-ire
State
Free Coal
Ash
Free Coal
Sulfur Si02 A1203 Fe203 Ti02 P205 CaO
MgO Na20 K20
SO 3
NORTHERN GREAT PLAINS PROVINCE
ru
o
Colorado
Montana
New Mexico
North Dakota
Utah
Wyoming
Min.
Ave.
Max.
Min.
Ave.
Max.
Min.
Ave.
Max.
Min.
Ave.
Max.
Mln.
Ave .
Max.
Min.
Ave.
Mai.
3-0
10.0
19.2
4.2
12.6
19.3
2.9
10.5
16.3
7,5
11.8
16.9
5.7
7.7
9.6
6.4
10.4
14.4
COAST PROVINCE
Washington
Min.
Ave.
Max.
6.1
10.6
22.4
0.4
0.7
1.1
0.4
0.6
0.9
0.6
1.3
3.2
0.5
1.0
1-5
0.4
0.8
2.2
0.5
1.2
1.8
34
50
71
21
35
53
28
49
61
15
26
40
39
51
63
24
31
38
.8
.4
.8
.9
.4
.6
.9
.2
.9
.0
.3
.4
.4
.4
.2
.5
.5
.6
15.2
26.8
34.2
13.8
21.5
31.9
14.3
21.6
30.0
8.0
12.1
16.8
9.1
15.1
20.3
14.2
16.9
19.6
3.2
6.1
11.9
2.9
5.3
8.0
3.6
13. S
27.3
4.1
6.9
10.1
3.7
7.4
19.3
9.0
9.6
10.3
1.0
1.3
1.7
0.6
0.8
1.2
0.9
1.1
1.3
0.6
0.7
0.9
0.6
1.0
1.3
0.9
1.3
1.8
0.01
0.5
2.8
0.02
0.4
0.76
0.02
0.06
0.12
0.04
0.2
0.42
0.03
0.6
1.4
0.21
0.36
0.51
0.4
6.2
12.8
1.8
13.4
31.4
1.7
6.4
14.0
14.5
21.1
36.0
3.5
11.8
21.9
9.4
20,1
30.8
0.4
1.1
2.9
1.4
4.6
10.4
0.8
2.0
4.2
3-3
6.4
10.8
0.3
• . 3
7.6
4.4
4.5
4.7
0.1
0.7
3.0
0.1
2.8
8.1
0.1
0.7
2.2
0.5
4.4
8.2
0.4
1.7
4.3
0.1
0.1
0.2
0.1
0.3
0.6
0.3
0.7
1.8
0.1
0.6
1.1
0.1
0.3
0.6
0.1
0.6
1.4
0.5
0.5
0.6
0.2
5.2
15.1
2.4
13.3
26.2
0.5
4.7
17.3
16.6
20.6
27.4
1.8
6.0
8.6
14.4
15.2
16.1
0.4
0.5
0.5
37.2
45.9
54.1
29.7
33.5
33.2
2.8
5-6
9.2
1.2
2.3
4.7
0.18 1.7
1.7 3-1
2.6 7.6
0.9
1.5
2.6
0.2
0.7
1.5
0.6
1.1
1.7
1.0
3-5
10.5
from Table
-------
GENERAL COMMENTS
The PF Integral-Furnace boiler is one of the well-standardized
types of widely used in industrial plants. With suitable
firing methods, oil fuel varying in characteristics from
bunker C to residual and bituminous coals of a wide range
in percent ash and fusion temperature may be burned success-
fully. Pulverlzed-coal firing is not used for this unit.
The range in vertical height of unit (a series of 5 standard
dimensions between upper and lower drums), which in turn
affects the other two dimensions, permits a size selection
for comparable performance to suit many existing space con-
ditions of headroom and floor area. The space conditions
required for either spreader-stoker or chain-grate firing
are comparable.
No major changes in the boiler unit are involved in conver-
ting from oil and gas to coal firing or the reverse. The
"saturated" surface components are generally not affected.
There are minor alterations to brickwork to suit the new
firing equipment, and if a superheater is present, it may
be necessary to add or remove some surface to meet changed
combustion requirements (chiefly excess air) of the new fuel.
When fuel saving justifies the expenditure, economizers and
air heaters may be added, as in most boiler types, to utilize
low-level heat. However, of the more than 1500 type PP
boilers placed in service In the period 1940-1960, less than
10 percent were equipped with air heaters or economizers.
The proportion of boilers equipped with these additional
heat traps will tend to increase as fuel prices rise.
Figure 58. Type PF integral-furnace boiler69
69Anon. Steam/Its Generation and Use. 37th Edition.
New York, Babcock and Wilcox Company, 1963. p. 23-13
207
-------
SIDE VIEW THROUGH 3rd PASS.
OIL & GAS FIRED
PLAN VIEW
SIDE VIEW THROUGH l.t PASS.
SPREADER-STOKER FIRED
GENERAL COMMENTS
The FP Integral-Furnace boiler is particularly well suited for
stoker firing. With its completely water-cooled furnace, the
rates of heat input and heat absorption may be somewhat higher
than for the type FF boiler. Travel of the gas through the
boiler has been arranged so that the abrasive particles are
not concentrated in streams.
Oil and p;as firing, either singly or in combination, is en-
tirely suitable and may be used initially as an alternate to
stoker firing. Permanent conversion from one fuel to another
is as simple for the type PP boiler. Installation of oil and
gas burners in the side walls of a stoker-fired unit permits
combination firing, either simultaneously with coal or
separately. When firing oil and gas alone, the stoker must
be protected with a suitable tile or ash coating. The unit
is not designed for pulverized-coal firing. If the fuel
saving justifies the expenditure, economizers or air heat
should be installed.
The type FP boiler is well suited for the production of
steam for both industrial and power requirements. A highly
trained operating staff is not required for its successf
operation.
Figure 59. Type PP integral-furnace boiler69
69
p
208
-------
SECTIONAL SIDE VIEW.
OIL AND GAS FIRED
1=.
-*.
Jf lim
PLAN CROSS SECTION
SHOWING HORIZONTAL
GAS FLOW PATH
SECTIONAL SIDE VIEW,
PULVERIZED-COAL FIRED
FLAT FLOOR FOR ASH RAKE-OUT
SECTIONAL SIDE VIEW.
PULVERIZED-COAL FIRED
WITH ASH HOPPER
GENERAL COMMENTS
The PH Integral-Furnace boiler is particularly well suited
for pulverized-coal firing and is widely used for maximum
outputs from 50,000 to 350,000 Ib of steam per h^. With its
furnace construction of touching tubes, except for refractory
areas around the burners, it is designed for moderately high-
duty service. Heat liberation rates may be correspondingly
nigh per sq ft of furnace area per hr for a coal ash-softening
temperature of 2500°F, oxidizing basis, with rates reduced
for lower ash-softening temperatures. The allowable heat
liberation rates are generally lower for the flat-floor than
for the hopper-bottom arrangement.
Standard superheaters, both inverted and pendent types, are
available to suit the specific application. Where constant
steam temperature is required over a considerable load range,
an attemperator is installed in the lower drum. Air heaters
are invari.ibly necessary to provide hot air for drying the
coal and as an aid in combustion, they are also usually
justified by the fuel saving. With high fuel costs, econo-
mizers are also sometimes justified.
Figure 60. Type FH integral-furnace boiler6
23-16.
209
-------
The ash sodium content appeared to have the greatest effect
on the fouling rate. The fouling rate was found to in-
crease rapidly with increasing sodium content at low sodium
contents. It leveled off, however, at 8 to IQ% sodium con-
tent. It was also found that high calcium content reduces
the effect of sodium on the deposition mechanism. The coal
ash composition ranges given in Table 4? show that North
Dakota and Montana coals have ashes containing the largest
quantities of sodium. Wyoming coals appear to have the
lowest sodium content suggesting that they are less prone
to fouling.
Other factors affecting the ash fouling rate, which were
also studied by these authors, include the percentage of
excess air, tube metal temperature, fuel moisture content
and gas temperature at the probe bank. It was found that
no significant effects on fouling rate were produced by
changes in the fuel moisture content or the percentage of
excess air. An increase in the fouling rate was observed
as the probe metal temperature was increased from 800°F to
1200F0. When the flue gas temperature was increased from
1800°P to 2100°F, a similar Increase in fouling rate was
observed. Various chemical additives were studied as a
means of reducing deposition rate and deposit strength,
but no additive was as effective as reducing the sodium
content from 6 to 1%.
Reid points out the fact that the properties of the coal
ash mainly affect the way in which the coal is burned.7°
He also states that the significant factors related to the
70PP- 38-51.
210
-------
coal ash are its fusibility, which establishes limits for
temperature during and after combustion, and its contribution
of chemical reactants that lead to external corrosion of
heat-receiving surfaces exposed to the products of combustion,
The problem of clinkering is related to the ash softening
temperature, and coals may be placed into four broad cate-
gories based on softening temperature as shown in Table 48:
low fusion, moderate fusion, high fusion, and refractory
(although fuels technologists may disagree on the limits of
the classes). The inorganic matter in coal which is respon-
sible for external corrosion of superheaters and reheaters
is composed of alkalies and sulfur. Garner71 has developed
an equation by the use of regression analysis which relates
the fouling tendency of Australian brown coals to the
percentages of S102, Pe203, CaO, MgO and Na20 in the ash.
Again, sodium was found to be the major factor in fouling
rate.
Table 48. COAL ASH CLASSIFICATION70
Low fusion
Moderate fusion
High fusion
Refractory
Range, °P
1800-2100
2100-2400
2400-2700
2700-3000
71Garner, L. J. The Formation of Boiler Deposits from the
Combustion of Victorian Brown Coals. J. Inst. Fuel.
40(314):109-116, 1967.
70p. 40.
211
-------
^4.3-4 Corrosion of Boiler Tubes
The processes involved in external corrosion have been summar-
ized by Reid as follows:70
1. Sodium and potassium are volatilized in part
from ash constituents in the 3000°F flame.
2. Pyrites are dissociated thermally, and with
the organic sulfur in the coal, provide 2000
to 3000 ppm S02 in the flue gas.
3. About 1 percent of the sulfur in the coal
appears in the flue gas as S03 by reaction of
S02 with oxygen atoms present in the flame.
4. The volatilized sodium and potassium thus are
converted at least in part to the sulfates, and,
with the unconverted oxides, deposited on the
relatively cool metal surfaces where the
sulfation reactions continue, ending up with
a thin layer of Na2S(\ and K2SOk on the Pe203
outer layer of the oxide scale.
5. Ash particles are captured by this sulfate
layer and eventually a moderately thick layer
of ash builds up on the tube surface.
6. Sulfur dioxide present in the flue gas reaches
the interface between Fe203 and the alkali
sulfates, and in the presence of excess 02,
oxidizes to S03 on the catalytic Fe203 sur-
face. Apparently this reaction reaches near-
equilibrium levels of S03, and almost certainly
it is responsible for a concentration as high
as 1000 ppm of S03.
70PP. 50-51.
212
-------
7. At such high concentrations of S03, reactions
occur with the Pe203 and the alkali sulfates
to form Na3Fe(SOlt)3 or K3Pe(SOit)3, which are
molten at about 1100°F in a high-S03 atmosphere.
8. These molten trisulfates can provide an
electrolyte for further corrosion by galvanic
action, but essentially they remove the ad-
herent outer layer of Pe203 always present on
tube scale, so that the tube oxidizes further
to replace its normal scale at that temperature.
The major argument against this mechanism is that
the trisulfates may be formed, not by reaction
between S03 and alkali sulfates with the Fe203
on the tube surface, but with the Fe203 present
in the ash deposited on the tube. The resulting
trisulfates are then thought to migrate to the
tube surface along the temperature gradient exis-
ting in the deposit. At the tube surface, the
trisulfates would react with iron, causing wastage.
The reactions are as follows, with potassium be-
having similarly:
3Na2SC\ + Fe203 + 3S03 * 2Na3Fe(S0lf ) 3 (2)
lOFe + 2Na3Fe(SOit)3 * 3Fe304 + 3FeS + S^SOi, (3)
Reaction 2 proceeds whether the source of the Fe203
is the tube scale or the ash deposit. Reaction 3,
which can only occur if the trisulfates have been
formed first in the ash deposit, will take place
only if metallic iron is in contact with the tri-
213
-------
sulfate. It is difficult to see how this can be,
since no iron is ever exposed at these temperatures,
only an oxide scale; no reaction has been identi-
fied between iron oxides, and the trisulfates.
Nevertheless, the fact that reaction 3 does occur
at least occasionally is shown by the presence of
small amounts of FeS at times in corrosion areas.
This is possibly explainable by cracks or imper-
fections in the oxide scale exposing elemental Pe.
Whichever mechanism predominates, it is evident
that coal ash, other than supplying the needed
alkalies and sulfur, takes part in corrosion mainly
by supplying the proper environment for the for-
mation of S03 at a high enough level to form the
trisulfates.
4.4 WESTERN COAL COMBUSTION
Holyoak has described .some of the problems associated with
burning western low sulfur coals in equipment designed to
burn midwestern coals.72 Some of the characteristics of
the coals used in the study are given in Table 49. The
problems described include dust formation, a reduction
in boiler capacity, different slagging characteristics, a
reduction in electrostatic precipitator efficiency and
ash handling problems.
Holyoak, R. H. Burning Western Coals in Northern Illi-
nois. (Paper presented to the Fuels Division of the
American Society of Mechanical Engineers at the Winter
Annual Meeting, Detroit, Michigan, November 11-15
pp. 1-9.
214
-------
Table 49. COMPARISON OF WESTERN
COAL AND TYPICAL ILLINOIS COAL72
ro
Property
Sulfur, %
Heating value,
Btu/lb
% Reduction Btu
compared to
Illinois
Moisture, %
Mine and state
Colstrip
Montana
0.65
8,630
18
26
Arch Mineral #1
Wyoming
0.38
9,770
8
in
Arch Mineral #2
Wyoming
0.33
10,590
0
14
Decker
Montana
0.31
9,640
9
23
7
Illinois
3-5
10,600
-
17
72
P- 3.
-------
The western coals used in Holyoak's study were friable and
broke easily on impact. This caused the production of a
considerable amount of fines during the 1200-mile train
trip to the utility stations where the tests were conducted.
Although the Arch Mineral coal received about 1.5 gallons
of oil per ton of coal at the mines, dust problems were
great enough to require the installation of special dust
control equipment for use of western coals.
The decrease in boiler capacity for western coal, compared
with the coal for which the equipment was designed, was
caused by the reduced coal conveyor belt capacity due to
the lower density of the western coals and by the reduced
pulverizer mill capacity due to the coal's lower heating
value. The reduced grindability of the Decker and Colstrip
coals, caused by high moisture content, further reduced the
pulverizer mill capacity because of the increased coal re-
circulation within the mill. The mill capacity was improved
somewhat by increasing the mill feeder capacity. Wet
western coal fines were found to plug feeder chutes more
than wet Illinois coal fines. No change in pulverizer
maintenance was reported.
Differences in slagging characteristics were rated in Holy-
oak's study. Burning low sodium western coal caused very
low slagging of the wall and superheater sections of the
boiler compared with slagging when Illinois coal was burned.
However, the resulting increased heat transfer rate increased
the rate of scale buildup on the water side of the heat
exchange surfaces. The acid tube cleaning procedures were
increased from 5-year to 3-year intervals to correct the
216
-------
problem. When high sodium coal such as Decker coal was
burned in a pulverized coal boiler, increased fouling rates
were encountered. It was found that the deposits could be
easily removed by increasing the soot-blowing frequency
and pressure. Additional sootblowers were needed in only
one case.
The decrease- in collection efficiency of electrostatic
precipitators (ESP's) in installations burning low-sulfur
coal is a well known fact. The efficiency decrease is
generally thought to be caused by high flyash resistivity
of certain low sulfur coals. The flyash resistivity
characteristics for coals with varying sulfur content
between temperatures of 200 and 450°F are shown in Figure 6l.
The flyash resistivity is shown to be most strongly affected
by temperature as the coal sulfur content decreases. For
this reason the operation of ESP's in a "hot" temperature
mode can increase the efficiency to normal levels (95f° )•
Resistivity of flyash is not affected solely by sulfur
content in the fuel. It is a function of interacting varia-
bles such as temperature, composition, surface phenomena,
etc. One recent significant discovery was the positive
correlation of resistivity to sodium content in flyash.
Figure 62 shows data obtained for a group of western power
plants. An increase in sodium concentration in flyash de-
creased the resistivity of the flyash and made the efficient
collection possible with certain low-sulfur western coals.73
This discovery may lead to the possible incorporation of
sodium injection flyash conditioning as an effective method
of increasing ESP collection efficiencies for low-sulfur,
low-sodium coal burning installations.
73p
217
-------
250
300 350
TEMPERATURE, °F
400
450
Figure 6l. Fly ash resistivity as a function
of temperature and coal sulfur content72
72p. 8.
218
-------
u
>-
>
co
UJ
ce
a:
CO
-------
Although the ashes from the western coals used in Holyoak's
study were easily sluiced, they had a fine consistency and
were difficult to dewater.72 These western coals also have
ash with high calcium content which readily dissolves in
water. This gave higher dissolved solids content to water
treatment plant effluents. The high calcium oxide content
of the western coal flyash with its affinity for water causes
the sluiced flyash to flow less easily (higher viscosity)
and to set up and harden easily after dewatering.
For western coal flyash Holyoak recommended that the dust
handling system be larger or be modified to keep the dust
hotter within the collection device.
The TVA conducted tests at the Johnsonville steam plant on
the burning of low sulfur Montana coal.7" The two steam
generation units tested were a corner-fired pulverized coal
Combustion-Engineering boiler designed to produce 1,000,000
pounds steam per hour and a rearwall-fired pulverized coal
Poster Wheeler reheat steam generator of 1,100,000 pounds
steam per hour capacity. The fuels used in these tests
were Montana coals with 27-55? moisture, 1.6% sulfur (dry
basis), and a heating value of 7865 to 8999 Btu per pound
(as fired), and Kentucky coals with 10% moisture, 3.3%
sulfur (dry basis), and heating value of 9975 to 10^16 Btu
per pound (as fired).
A 35-5? reduction in generating capacity was observed when
burning low sulfur Montana coal in the Foster Wheeler unit,
compared with the performance of Kentucky coal. With the
72
p. 6.
7l*McKinney, W. Tennessee Valley Authority, Division of
Power Production. Personal Communication.
220
-------
Combustion Engineering unit, a 15% reduction in generating
capacity was observed. The reductions resulted from the
inability of the coal feeder-pulverizer-exhauster systems
to handle the increased quantity of low heating value coal.
The TVA tests also reported that the higher moisture content
of Montana coal caused a loss in boiler efficiency due to
higher heat loss up the stack (about 2.5% higher loss).
The heat loss results from utilization of boiler heat to
supply the latent heat of vaporization to vaporize moisture
in coal. The total carbon loss (Section 4.1) up the stack
for Montana coal was found to be lower than for Kentucky
coal. Furnace slagging was reduced when Montana coal was
burned.
It thus appears that the conversion of existing high sulfur
power plants to low-sulfur western coals is not a simple
matter. The overall difference in burning this fuel lies
in the inherent problem of operating the plant outside of
its designed operating limits. The operating parameters
which were affected by western coal's characteristics are
summarized below. These factors must be considered prior
to large scale conversion to western coal.
1. Excessive dusting of coal en route to power plant.
2. Reduced conveyor belt capacity.
3. Decreased pulverizer output (if so equipped).
l\. Loss of boiler efficiency.
5. Water side scale buildup due to decreased slagging,
6. Increased fouling with high sodium coal.
221
-------
7. Decreased ESP efficiency when low sodium coals
are utilized necessitating hot ESP operation;
injection of sodium or other resistivity de-
creasing chemicals may be needed.
8. Ash dewatering difficulty and caking.
9. Increased sluiced ash viscosity.
10. Larger dust handling system requirements.
222
-------
SECTION 5
ENVIRONMENTAL EVALUATION OP WESTERN COAL
MINING AND UTILIZATION
The dramatic escalation in the mining and utilization of
low sulfur western coal deposits has created much concern
for the environment. Development of mining western coal
must be accomplished with a minimum of adverse effects on
the environment. The long-term effects of widespread sur-
face and underground mining on the environment are not
well defined or characterized in this arid and semi-arid
region.
A recent study on coal energy development in three northern
Great Plains states (Wyoming, Montana, and North Dakota)
provides an excellent summary of environmental areas that
need additional definition, as outlined in Table 50. It
should be noted that these study areas apply equally to all
western coal states.
This section identifies potential hazards to the western
environment as a result of coal mining. Hazards discussed
include land disturbance as a result of strip mining, re-
vegetation and recontouring problems of reclamation, and
coal refuse disposal. The effects of western coal trace
elements on the environment are briefly discussed. Lastly
the sulfur emission characteristics of western coals are
discussed in relation to small and intermediate size
boilers. A relationship is presented which can serve as a
guide when choosing a western coal to meet the S0x emission
standard.
223
-------
Table 50. STUDY NEEDS, COAL INDUSTRY DEVELOPMENT
NORTHERN GREAT PLAINS75 '
(tentative)
High Priority
A. TRACE ELEMENTS
1
2
3,
Baseline studies of trace elements
Trace elements in regional coals
Trace elements & inorganics in coal
by-products
B. ATMOSPHERIC EFFECTS
1.
2.
3.
Air quality management systems
Air quality baselines and air shed
dynamics
Atmospheric mobilization of
combustion factors
Atmospheric effects by diffusion
modeling
C. COAL RESOURCES AND MINING TECHNIQUES
1. Identify strippable coal deposits
2. Appraise strip mining techniques
3. Waste disposal
D. SURFACE RESOURCES
1.
2.
3.
H.
Surface resources threatened by
coal development
Land use alternatives
Interpretative geological
analysis
Coal development & biological
ecosystems
E. SURFACE RESOURCES (RECLAMATION)
1. Reclamation and land use options
2. Methods for mining & handling spoil
banks
Wyo., Mont.
Wyo., Mont.
3 states
Montana
3 states
Mont., N. D,
Mont., N. D,
3 states
3 states
3 states
Mont., N. D,
3 states
3 states
3 states
Wyo., N. D.
Wyo., N. D.
75Anon. Water Resources Research Institutes of Wyoming
Montana and North Dakota. Coal-Energy Development in'the
Northern Great Plains. Laramie, Wyoming. NTIS Pub 11 cat-irm
P.B-231560, October 1973- pp. 1-
224
-------
Table 50 (continued). STUDY NEEDS, COAL INDUSTRY
DEVELOPMENT, NORTHERN GREAT PLAINS75
(tentative)
High Priority
3-
4 .
5.
6.
Soil, water & revegetation programs
Combination of plants for
revegetation
Propagation & cultivation of native
plants
Clearing house for mine site
revegetation
3 states
3 states
Montana
3 states
F. WATER RESOURCES
1.
2.
3-
4.
5.
6.
7.
8.
Computer models for water planning
Water availability
Water requirements and options
Ground water potential
Instream values of water
Effects of strip mining on wells
Multiple use options for water systems
Recreational values for water options
Wyo . , Mont .
N. D.
Wyo. , N. D.
3 states
Wyo . , Mont .
Mont . , N . D .
3 states
3 states
G. WATER QUALITY
1.
2.
3-
4.
5.
Water quality data evaluation
Hydrology of development sites
Effects of coal industry on water
quality
Effects of strip mining on aquifers
Salinity changes & downstream effects
3 states
3 states
3 states
3 states
Mont . , N . D .
H. GENERAL TECHNOLOGY DEVELOPMENT & OTHER
1.
2.
Technologies for conservation of
energy
Waste heat reduction & water conser-
3 states
3 states
tion in power plants
3. Improved stack emission control
4. Water saving technologies vs. water
development
Wyo., Mont
Wyo., Mont
75
pp
225
-------
5.1 ENVIRONMENTAL ASPECTS OP MINING
Land area disturbed by surface coal mining may be used as
an indicator of environmental impact. Potential land
disturbances for 1*1 states resulting from strip mining
are shown in Table 51.
The potential land disturbance L (%} is defined as follows:
(Ap + A )
L = ^— ^ x 100 (1|)
AS
where A = square miles of state coal land previously
disturbed (1930-1971)
AR = square miles of land disturbed if remaining
strippable reserves are entirely recovered
AS = total square miles of state area
The land area previously disturbed by strip mining, A ,
was obtained from data of Paone et al.76 The figures
compiled in this report are for the period between the
years of 1930 and 1971. The remaining area, An, was
n
computed by the following relation:
n W
.
A = - V —
where W^ = tonnage recoverable from individual deposit
p = assumed coal density (84.2 lb/ft3)
hi = average coal seam thickness in feet
n = number of individual deposits per state
76Paone, J., J. L. Morning, and L. Giorgetti. Land
Utilization and Reclamation in the Mining Industry,
1930-71. Bureau of Mines Information Circular. 8642
1974. pp. 11-61.
226
-------
Table 51. POTENTIAL LAND DISTURBANCE IN THE
WESTERN STATES AND SELECTED NON-WESTERN STATES
State
Arizona
Colorado
Montana
New Mexico
North Dakota
Oregon
South Dakota
Utah
Washington
Wyoming
Total West
Illinois
Kentucky
Ohio
West Virginia
Total land
area
AS (sq mi)
113563
103797
145603
121445
69280
96209
75956
82381
66663
97281
972178
55877
39851
41018
24084
1968 total land
underlain by re-
maining strippable
coal reserves
AR (sq mi)a
33.0
35.1
312.3
196.8
127.8
0.06
27.3
11.6
5.21
232.2
981.4
776.4
188.1
230.5
443.0
Million tons
per square
mile
remaining
11.7
14.2
22.1
12.6
16.2
4.9
5-9
• 12.9
25.9
60.2
—
4.2
4.2
4.5
4.8
Coal land
previously
disturbed
(1930-1971)
Ap (sq mi)
0.34
13-5
10.6
12.9
42.5
0.03
0.48
5.03
2.1
15.8
103.3
365.6
328.1
323.4
306.2
Potential
disturbance
by surface
coal mining" L (%)
0.03
0.05
0.22
0.17
0.25
9-3 x 10~5
0.04
0.02
0.01
0.25
0.11
2.04
1.29
1.35
3.11
rv>
^Does not account for land disturbed prior to 1968.
'Total disturbed land area after all presently known deposits are mined out
-------
Data for equation (5), W± and h1, were supplied from a
Bureau of Mines report which presented strippable coal
reserves remaining in the ground as of 1968.2 The seam
tonnage and average seam thickness were used to calculate
remaining land disturbance for each state in Table 51. The
following assumptions were made:
a) All of the coal deposits lie flat (horizontally)
in the ground
b) All of the coal is eventually recovered by mining
The only data available to check equation (5) were from
Wyoming with a reported AR of 235-5 square miles.19 The
computed AR is 232.2 square miles. It is not known how the
reported figure was derived.
The 3-year period between 1968 and 1971 is not accounted
for in land disturbance due to lack of available data.
Additionally, the estimates of recoverable tonnage per
seam, W±, are thought to be very conservative Judging from
the updated figures published for some of the seams in more
recent reports. Thus, the land disturbances, L, presented
in Table 51 should be regarded as relative and should be
corrected whenever new and more accurate data become
available.
Several observations nonetheless, can be extracted from
Table 51. It appears that potential land disturbance
in the West is minimal from a percent-of-area disturbance
standpoint when compared to non-western locations. The
coal seams in the western areas are thick as seen from
2pp. 70-121.
IV 125.
228
-------
the tonnages per square mile. Wyoming appears to be the
most difficult state to reclaim to original contours because
of the "crater effect" of deep open pits. The difficulties
lie in the depletion of fill material for these pits in flat
regions. The potential land disturbance figures as calcu-
lated above do not account for future disposal of waste from
surface stripping or for waste from underground mining.
The heterogeneous overburden mix produced by conventional
strip methods can lead to revegetation problems in the West
and Southwest. Displacement of surface soils by highly
saline materials from under the surface in some areas makes
vegetation growth difficult. Rainfall would displace these
materials eventually, but this can take hundreds of years in
the arid portions of the West.
One method of surface mining recently proposed would mini-
mize deep open pits and not disturb fragile top soil
structure. This is longwall stripping, a promising new
surface mining concept. It adapts existing underground
longwall mining technology for use in recovering shallow
cover coal without the total environmental disturbance
often associated with surface mining. A recent EPA spon-
sored study investigated the environmental, mining and
economic feasibility of longwall stripping.77 This method
was determined to be feasible for mining coal under shallow
cover for selected overburden structure as described in
Section 3.2.1. Longwall mining calls for controlled caving
77Anon. Environmental Pollution and Control. NTIS Weekly
Government Abstracts, p. 363, August 19, 1974.
229
-------
of the mined out area as mining progresses. Surface caving
is much less damaging environmentally than removal and
relocation of overburden used in conventional stripping.
Pull reclamation of land can minimize the damages to the
environment. Pull reclamation as is called for in proposed
legislation consists of returning the land to near original
contours with best soil materials on top. Toxic substances
including acid-forming materials must be deeply buried.
If siltation due to erosion can occur, water catch basins
must be provided. The land must be managed for a period
of years to restore nutrient and humus levels of the soil.
Vegetation proven to be adaptable to a particular area
must be planted and maintained. Some recent success on a
laboratory scale has been obtained using mountain rye,
fourwing saltbush and western wheatgrass in New Mexico.78>79
The sparse vegetation present originally indicates that
many years must pass before revegetation can be considered
successful on a large scale.
Full reclamation is expensive. Recent estimates made on
the Appalachain region appear to be of the order of $1500
to $4000 per acre.33 Requirements include backfill, top-
soil replacement and revegetation. Costs to fully reclaim
western pits are expected to be higher because of the
substantial quantity of additional earth needed to fill the
pits after the coal is removed. The Black Mesa mine
transports coal ash back to the Arizona mine from the Mohave
78Aldon, E. P., o. D. Knipe, and G. Garcia. Revegetating
Devastated Sites in New Mexico with Western Wheatgrass
Transplants. Rocky Mountain Forest and Range Experiment
Station. Research Note RM-243. June 1973. p. 3.
79Aldon, E. P., and H. W. Springfield. Revegetating Coal
Mine Spoils in New Mexico. Rocky Mountain Forest and
Range Experiment Station. Research Note RM-245. June
1973- P. 4.
-------
power plant to minimize contour damage. The Cholla power
plant in Arizona routinely ships ash back to the Navajo mine
in New Mexico. Non-toxic solid waste materials from mid-
western coal destinations have been proposed as fill material
for the coal pits of Wyoming. It has also been brought out
that it is impossible to ever reclaim large strip areas to
original contours because fill dirt would have to be stripped
from non-coal regions to fill the huge western pits. Clearly,
this problem needs further definition.
There are examples of successful reclamation in the West.
One of these is the Big Horn coal mine in Sheridan, Wyoming.80
This area is classified as semi-arid with 15 to 16 inches of
precipitation annually. The spoil piles were graded to a
rolling topography and care was taken to restore the ori-
ginal topsoil. Revegetation techniques used were fertilization
sprinkling and the use of native tree seedlings and imports
that thrive in arid climates. Water impounded in worked
out areas is considered valuable since it does not become
acidic (because it is mostly groundwater which tends to flow
rather than stagnate). The low sulfur coal seams also tend
to alleviate acid water buildup. The original topsoil
needed to sustain growth is exceedingly thin in this area,
running from two to six inches, and attempts to put soil
back in its original state were difficult in some instances.
Reclaimed spoil material was allowed to weather for one or
two years in order to develop a surface that would permit
germination of seed. Rye, oats and pasture-mix seeds were
planted with success following artifical irrigation. Cara-
, J. P. Reclamation at Big Horn Mine. Mining
Congress Journal 57:42, June 1971.
231
-------
gana and Russian olive seedlings were included in the
planting. All varieties of seedlings had a high percentage
of recovery.
The Black Mesa mine in Arizona has not been as successful.81
Unsuccessful revegetation appears to characterize this arid
region. Mined land is being acceptably regraded but little
success is reported on revegetation due to comparatively
little research on the general problem of mined land recla-
mation in this area. The Navajo mine in New Mexico near
Pour Corners also has not effected acceptable recontouring
or acceptable reseeding according to the Department of
Interior.8l
Reclamation and revegetation in the West are clearly of a
different nature than In the interior or eastern provinces.
Mountainous eastern regions are difficult to recontour
because of excessive slopes. Areas of Ohio and Illinois are
less difficult to return to original contours because of
thinner coal seams than those found in some areas in the
West. Vegetation generally grows well in these non-western
regions.
The strip mining process itself can have an adverse effect
on the environment. Particulates and gases resulting from
coal mining and related operations stem from several major
sources. Nuisance particulates, coal dust, and silica-
containing dusts originate from the following sources:
81Bishop, F. 'Environmentalist!!' - Creating Crunch on
Coal Industry. Mining Congress Journal. 59:111
February 1973. '
232
-------
1. Haul roads
2. Drilling and blasting operations
3. Open rail car shipments to market
4. Reclamation operations and overburden handling
5. All coal handling and storage at mine site
6. Thermal dryers and air cleaning operations
7. Wind erosion
These sources are not well defined from an air emissions
standpoint. Extensive efforts now underway will character-
ize these emissions and determine areas where control tech-
nology is needed to prevent hazards to the general environ-
ment .
Roughly 21% of total western coal produced is currently sent
to some form of cleaning operation (Section 3.2.2). A
survey taken in 1968 showed that in Washington, Oregon and
Montana alone, 805 acres of land were covered with coal
cleaning waste in the form of refuse piles.82 This amounted
to over 36 million tons of washery refuse. The report fore-
cast than an additional 3 million tons of refuse would
accumulate in this region by 197^. These refuse piles act
essentially like spoil banks, causing windborne dust
contaminants and stream pollution from water leaching. More
serious are the fumes from self-igniting piles. Visible
smoke plumes from these mounds plus resultant S02, NO ,
X
CO and hydrocarbon-emissions present hazards not well docu-
mented. Based on a clean coal separation yield of 75%
obtained by arithmetically averaging washed coals throughout
82Qeer, M. R. Disposal of Solid Wastes from Coal Mining
in Washington, Oregon and Montana. Bureau of Mines
Information Circular 8430. 1969. p. 38.
233
-------
the U.S., the amount of washery refuse produced in 1972
was 1.25 million tons for the entire West.2* Techniques
practiced to eliminate burning are compaction and regrading
followed by planting.82 utilization of this refuse is more
desirable because it would eliminate the "gob piles". in
a few cases in the West, waste is being utilized, particu-
larly cinder from burned refuse dumps, as fill ±n road
construction and as a ceramic raw material.82
5.2 ENVIRONMENTAL EFFECTS OF WESTERN COAL TRACE ELEMENTS
Trace element accumulation in aquifers as a result of strip
mining operations is largely unknown. The greatest concen-
trations of trace elements in coals occur near the coal
seam partings. Coal seams form part of natural aquifers in
certain western regions. Under normal static conditions
the trace elements and carcinogenic material present in coal
leach out slowly minimally affecting water quality. The
spread of heavy metals or carcinogenic materials by rapid
leaching and dilution may occur when coal seam disruption
(i.e. mining) occurs.
The extent of trace elements in western coal is fairly well
defined form some western areas (Section 3.5). The long-
term effects on the environment as a result of combustion
and airborne dust are largely undetermined. The compo-
sition of western coal and its overburden must be known for
all minable areas to fully characterize and compare it with
coals east of the Mississippi River. How trace elements are
released and transported in the air as a result of combustion
21pp. 18-6.
82PP. 36-39, 1.
234
-------
or gob pile burning is not fully understood. The uptake
of transported trace elements in plant life, soils, and
water systems must be studied. In addition, the potential
hazards to human health from the utilization of coal
obtained from coalfields located near or within radioactive
ore deposits are undefined.
The increased utilization of trace element enriched by-
products such as ash and coal refuse needs environmental
definition. Ash has been used to promote successful revege-
tation of soil in the northern Great Plains area as described
by Freeman, et al.70 Use of fly ash in concrete roads has
been highly acclaimed by many.70 Sufficient data are not
yet available to assess these types of environmental
impacts.
5.3 SULFUR EMISSION CHARACTERISTICS
5.3.1 Total Sulfur
A question arises as to the sulfur emissions from small
and intermediate size boilers converted to low sulfur
western coal. Neglecting the derating of boilers which is
perhaps necessary when western coals are burned, what is
the net effect on sulfur emissions? The category of steam
plants generating up to 250,000 Ib steam per hour and requir-
ing 240 MM Btu/hr of heat input are considered to be repre-
sentative and inclusive of the terms "small" and "interme-
diate" size. The heat available to produce steam is defined
as follows:
70pp. 150-157, 138-149.
235
-------
= 1.935*10- [S|u|
103 tons
burned
yearly
(6)
Equation 6 relates the average yearly boiler capacity (Q)
to the coal heating value (Btu/lb) and the tons of coal
burned yearly. The above relation assumes a boiler
efficiency of 85% and latent heat of evaporation £ 950 Btu/lb
The cutoff points for small and intermediate size boilers
are:
10,000-100,000 lb steam/hr small
9.5-95 MM Btu/hr
100,000-250,000 lb steam/hr intermediate
95-240 MM Btu/hr
Total sulfur in coal is converted in the boiler to sulfur
In fly ash (solid) and to sulfur in stack (gas). It may
be assumed that total sulfur leaving the boiler is directly
proportional to the boiler coal feed rate and the % sulfur
in coal. A plot demonstrating the relationship between
the total sulfur (expressed as elemental sulfur) leaving
the boiler (millions of tons per year in stack and in ash),
boiler capacity (Q), and % sulfur in coal for two types of*
coal (6000 and 12,000 Btu/lb net) is shown in Figure 63.
Heat contents of 6000 and 12,000 Btu/lb were chosen to
indicate the maximum change one may expect when converting
from high quality subbituminous and bituminous coal to
lignitic fuel, it is apparant from the plot that without
a loss in boiler heating capacity, conversion of boilers
using high sulfur eastern coals can only be effective in
reducing total sulfur emissions from the stack and in the
ash if the sulfur content of western coal is less than
half of that for high sulfur fuel. For example, a boiler of
236
-------
uo
oc.
>-
a.
LINE PARAMETERS ARE % SULFUR IN COAL
AT CORRESPONDING Btu PER POUND
HEATING VALUE
160 180 200
INTERMEDIATE
0.4 -
40 60
• SMALL
Q, MMBtu/hr
Figure 63. Relationship between total sulfur leaving the boiler,
boiler capacity, sulfur in fuel, and heating value of fuel.
-------
180 MM Btu/hr capacity utilizing 3% sulfur and 12,000 Btu
coal would not experience a reduction in total sulfur
emissions if a 1.5* sulfur 6000 Btu coal was substituted.
Its sulfur tonnage would remain at 2.3 thousand tons per*
year (point A). Reducing the sulfur emissions to about half
this amount requires a four fold reduction in sulfur content
of the 6000 Btu per pound coal (point B).
The limitations of the plot in Figure 63 are that it only
shows the changes if conversion is made from coal with a
heating value of 12,000 Btu/lb to lignite of 6000 Btu/lb.
Should the change in heating values of the two fuels be
less dramatic, higher sulfur content of the substituted fuel
may be allowed.
Also, the vertical axis represents the total elemental sulfur
leaving the boiler in both ash and flue gas streams. The
sulfur emitted to the atmosphere, however, is of major concern
The distribution of total sulfur between the gas and ash
stream varies greatly with properties and composition of
coal and will influence emissions of sulfur to the atmos-
phere. In the following two sections an attempt is made
to quantify the distribution of total sulfur in fuel
between ash and flue gas.
5-3.2 Sulfur Oxides
A more meaningful representation of sulfur balance around a
boiler is in the form of S0x emissions through the stack as
a function of boiler heat input. Available data were com-
piled and are shown in Figure 64. The raw data are given in
Table 52.
238
-------
ru
OJ
1000
900
800
700
600
500
° 400
300
200
100
DATA POINT
o
o
COAL ORIGIN
NORTH DAKOTA (LOW SULFUR LIGNITE)
NORTH DAKOTA (LOW SULFUR LIGNITE)
NORTH DAKOTA (HIGH SULFUR LIGNITE)
WYOMING (LOW SULFUR SUBBITUMINOUS)
NORTH DAKOTA (MEDIUM SULFUR LIGNITE)
IOWA (HIGH SULFUR SUBBITUMINOUS)
PENNSYLVANIA (MEDIUM SULFUR BITUMINOUS)
ILLINOIS (HIGH SULFUR BITUMINOUS)
ILLINOIS (HIGH SULFUR BITUMINOUS)
2.9
2.5
*
0.7
1.6
2.4
2.8
*
1.6
•
15 30 45 60
SMALL*—
%
105 120 135 150 165 180 195 210 255 240 255
. INTERMEDIATE
Q, MM Btu/hr
Figure 64. SO rate as a function of boiler size
sulfur in coal given pe/data point; symbols identified in Table 55)
-------
The above data were compiled from three sources. The M. W
Kellogg report provided data on the amount of coal burned in
1972, along with sulfur content, calorific value and boiler
identification (except for the Illinois boilers). Average
yearly heat input per boiler on an hourly basis was calcu-
lated from annual Btu consumption found in the Kellogg
Report. It was assumed that boilers operated 366 days and
24 hours/day (8784 hours/year). Only values of average
yearly heat input which fell in the range of small and
intermediate size boilers were considered. The SO mass
rate of emissions per boiler and stoker type were found in
the NEDS Data Condensed Point Source Piles for Utility
Boilers, May 15, 1974. The criterion for correspondence
between the NEDS file and the Kellogg report was that boiler
nomenclature numbers were identical between the two file
systems. Because the nomenclature numbers are normally
designated by the utility company, the boilers identified
by the same numbers should be identical. Only those SO
values which were calculated by actual stack sampling or
material balances were included in Figure 64.
The Illinois boiler data were gathered from an EPA report
that gave S02 and S03 emissions in volume ppm for two boilers
burning high sulfur (3%) coal and fitting the small and
intermediate classification.85 S0x mass emission rates for
the Illinois boilers were calculated from the S02-S03 con-
centration figures and stack volumetric flow rates given.
Equation 7 was used to calculate the SO mass emission
rate for the Illinois boilers.
SO
x
[Ib/hr] = 1.021 x 10~5 [vppm S0x][stack gas rate scfm] (7)
85pp. 1-26.
240
-------
Table 52. EMISSIONS DATA83 » 81* > 8 5
:'.tate and (M l.y
WKSTKKN COA[, Pnt
North Dakota:
Heulah
Mandan
Jamestown
South Dakota:
Lead
Mobrldge
Total Number
of bollera
L -:H"
3
2
1
14
1
Average 3Ulfur
content and
state of origin
(wt-<)
0.7
North Dakota
0.7
North Dakota
3.0
North Dakota
0.1
Wyoming
1.1
North Dakota
KITDWKSTKRN AND KAST^RN COAL BOILERS
Towa:
Bridgeport
Pennsylvania:
puquesne
Illinois:
Unknown
Unknown
3
22
NA
NA
1.1
Iowa
1.6
Pennsylvania
2.8
Illinois
2.5
Illinois
2.1
Illinois
2.9
Illinois
verage calorific
value Btu/lb aa
fired
6970
6970
6671
8015
7900
10007
12271
12650
12650
13195
13195
Boiler
number
1
2
3
1
1
1
2
3
I
1
1
2, 3, 8, 9
4, 5, 6, 7
11, 12, 13
15, 16, 17
IB, 19
20
22
1
1
1
1
Type of
stoker
preader
toker
verflred
toker
verflrei]
toker
preader
toker
preader
tokor
overf ired
toker
overf ired
stoker
overfired
stoker
overfired
stoker
spreader
stoker
spreader
stoker
pulverize
dry
pulverize
dry
pul verize
dry
pulverlzei
ary
pulverise
dry
spreader
stoker
spreader
stoker
horizon-
tally
opposed
horizon-
tally
opposed
Heat
input
MM Btu/hr)
116.8
28.0
11.1
166.9
86.8
5.5
28.1
16.8
132.6
39.7
93.5
11.2
15.9
21.2
116.7
251.7
23?. 8
full lo
171.6
partial 1
sox
ppm dry
NA
NA
NA
NA
HA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
NA
I'tiB
13*?
oad
253.3 15/0
full load
171.2 17tl6
partial load
so,
Ib/hr
92.?
36.5
32.0
531.2
111.1
NA
19. 'J
Ih.O
107 .5
61.9
1146.1
25.8
78.5
212.1
203.9
r>:'5.1
791.1
598.1
997.1
798.7
gure 61
o
o
o
o
0
e
e
©
®
•
X
+
+
+
+
+
Y
Y
A
A
83Kahn, H. A. EPA Stack Gas Scrubbing, P0908, Data Preparation
ari'l Cost Analysis System. Systems and Users Manual. M. W.
K^llofj Company. EPA Contract Noa. CPA 70-68 and 68-02-1308.
January 197'i
I^NationrH Emission:! Dat;i System (NEDS). Computer Pile Listing
of Condensed I'olnt Sources for utility Boilers. May 15, 1971!.
85Cuffr, S, T. ami H. W. Gerstle. Emission from Coal-Fired Power
Plants: A Comprehensive Summary. National Air Pollution
Control Administration. 1967. PP- 3» ^» 13.
-------
Equation (7) assumes that the stack gas behaves as an ideal
gas (particulate free) and that the molecular weight of SO
is 64, that of S02. x
The general trend of Figure 64 seems to indicate that SO
}£
emission rate (i.e. S02, S03) increases with boiler size
and coal sulfur content even though there are significant
deviations from this trend. The Federal emission standard
of 1.2 Ib S02 per million Btu's fired is shown for reference
(1971 standard in effect). Some liberty was taken in
drawing the S02 line on an S0x plot. However, the majority
of S0x emissions originate in the boiler as S02 (with some
coal to coal variations) and it is felt that only slight
error is introduced by assuming all SO as S02. (Note:
X
the Illinois boiler data reported both S02 and S03 and showed
only negligible formation of S03).
All data points lying below the standard line in Figure 64
are seen to be representative of low sulfur western coal.
Boiler data points above the line do not meet standards.
The majority of the points which do not meet the standards
are seen to be indicative of intermediate and high sulfur
coals from the East and Mid-West. High and medium sulfur
lignite (3% and 1.1$ respectively) are seen to also be
above the standard as would be expected with the low heating
value associated with this coal. A notable exception is a
"low-sulfur" lignite burned at Mandon, North Dakota which
appears to be substantially above standard.
242
-------
No definite conclusions can be drawn from Figure 64 due to
unknown experimental accuracy of the data and lack of infor-
mation on intermediate size western coal burning boilers.
There is also some doubt as to the correspondence between
the NEDS data and the M. W. Kellog data used since they have
been generated for different base years. Our method of
calculating average yearly heat input probably resulted
in inclusion of some boilers larger than intermediate size,
but all boilers of small and intermediate size for which
data were available are included. Figure 64 indicates,
however, the extent of data availability as well as the
complexity of the decision that has to determine whether
western coal will or will not meet the sulfur emission
standard. Considerable scatter in the data suggests that
more variables than those shown in Figure 64 affect S0x
emissions. Examples of correlating variables which were
not available from the given data sources include percent
ash in coal, percent sulfur in ash, and fractional conversion
of S02 to S03 in the stack. It appears that each western
coal will have to be evaluated individually in relation to
meeting the sulfur emission standard and the following section
will attempt to provide a method of this evaluation utili-
zing data presently available.
5.3.3 Coal Selection Criteria
The somewhat sparse and inconclusive data shown in Figure
64 only partially explain why there is an increasing in-
terest in western coals as purporters of low sulfur
emissions. It was seen that western coal burning boilers
In the small and intermediate size class can meet Federal
standards of 1.2 Ib S02 per million Btu's of heat input
even though some noteworthy exceptions to meeting the stan-
dards can exist.
243
-------
When burning low sulfur coals the retention of sulfur in
the ash becomes an important and influencing parameter for
determination of sulfur emissions through the stack. It is
apparent from a sulfur .material balance that the more sulfur
that is retained or bound in the ash, the less will be
emitted to the atmosphere. The following example will
illustrate the importance of bound sulfur in coal ash.
Let us consider two coals with the following properties:
% Ash % S Sulfur in Ash
Coal Btu/lb (as fired), in coal in Coal (Reported as
A
B
9,000
13,500
9
9
0.7
3-0
4.5
9.0
The total sulfur material balance can be expressed as
follows:
Scoal = Sstack + Sash
Sulfur in stack, Sstack, is subject to Federal standard of
1.2 lb S02 per 106 Btu's boiler heat input (0.6 Ib S per 106
Btu's). In order to express the Sstack in the unit of the
standard, Scoal and S&sh will be modified as follows:
X
o
b
coal Btu
„„ nrt ash
= 32xl0
Sash 80 Btu
-------
'•/here X = sulfur content of coal in %-wt
s
Btu = the heating value of coal in Btu/lb
X0~ = sulfur content of ash (as S03) in %-wt
SO 3
X = ash content of coal in %-wt
ash
Combining Equations (9) and (10) with Equation (8) yields
SstaeK
-------
in ash Is at least H.5% (expressed as %S03 in ash). The
coal B with double the sulfur retention in ash (9#) cannot
meet the standard.
Figure 65 summarizes the sulfur retention concept for
typical eastern and western coals with respect to the EPA
standard. In constructing this figure coals having 0.7%
sulfur and heat values ranging from 6000 to 11,000 Btu per lb
were chosen to represent western coals. Coals in the heat
value range from 10,500 to 14,000 Btu per lb and 3% sulfur
in coal were chosen to represent eastern coals. All coals
were assumed to have 9% ash In coal. If no sulfur is con-
tained in the resulting ash, it is seen that both the 0.1%
and the 3% sulfur coals do not meet the emission standard
(lines 1 and 3) for any heating value. However, if 5% sulfur
remains in ash the 0.7% sulfur western coals meet standards
readily for the entire heating value range (line 4). Even
with 5% sulfur in ash the protrayed eastern and midwestern
coals cannot meet the standard (line 2).
The amount of sulfur trapped in the ash along with low
inherent sulfur in coal are both important for low sulfur
emissions. Using the data of Table 28 an indication of sulfur
ash contents in western, interior, and eastern coals may be
obtained. These data are presented in Table 53.
As shown in Table 53, western coals appear to have higher
affinity for sulfur in coal ash (maximum %S average in ash *»'-•
8.2 versus 1.2 and 0.8 for non-western coals). Neither in-
terior nor eastern province coals meet the 5% sulfur in ash
best case assumption used in Figure 65.
246
-------
ro
3.0
2.5
£ 2.0
O*
i.o
0.5
9% ASH IN COAL
0.7% S IN COAL 5.0% IN ASH
6000
7000 8000
9000 10,000 11,000
Btu PER POUND (ASPIRED)
12,000 13,000 14,000
Figure 65. Comparison of 9% western and
eastern coals at Q% and 5% sulfur in ash
-------
Table 53. SULFUR RANGE IN COAL ASH
(reported as S03 from Table 28)
ro
-Cr
CO
Region
Western states
Interior province
Eastern province
Average range
% S03 in Ash
3-6 -
1.1 -
1.6 -
20.6
3.1
2.1
Average
% S in
1.4 - 8
0.4 - 1
0.6 - 0
range
ash
.2
.2
.8
Minimum3
% so3 % s
0.2 0.08
0.2 0.08
0.2 0.08
Maximum3
% SO %S
27 .4 10.
10.3 4.
9.6 3.
96
12
84
*S = 0.4 x % SO.
-------
The selection of western coal for SO reduction cannot simply
be based on % sulfur in coal and coal heating value. The
minimum sulfur content in coal ash in western coal can be
as low as 0.08% as seen in Table 53. This indicates that
some of the western coals, even though having low coal
sulfur content, may not be able to meet the EPA regulation.
In light .of this the high SO value shown by the Mandon,
South Dakota plant which burns 0.7$ sulfur coal (6970 Btu's)
appears reasonable if the sulfur content in ash of this coal
is low (see Figure 64). However, this could not be veri-
fied since the ash sulfur content was not available.
The superior retention of sulfur in some western coal ash
perhaps explains why some power plant operators mix selected
western coals with high-sulfur coal to meet the S02 emission
standard. The sulfur retention by ash is a function of ash
alkalinity, ash fusibility and perhaps other ash and coal
combustion properties that influence the boiler design.
As such, the sulfur ash content should be considered an
important variable in converting existing boilers to
western coal fuels and in determining the sulfur emissions.
In selecting western coals which can meet the S02 standard it
is thus important to know the minimum value of % sulfur in
ash. A relationship based on Equation 12 is proposed as a
tentative guideline to facilitate coal selection. In order
for a coal to meet the present standard, S* . . must be <.
1.2 lb S02/106 Btu. Substituting this value in Equation (12)
and after some rearrangement of the variables we obtain:
x (X - 0.6 Btu x lO'M (13)
<,n Q
303 v s
ash
-------
The fractional conversion of S02 to S03 (YSQ ) is usually
quite small for all coal fired plants. For completeness,
however, this factor is included since it may aid in the
experimental verification of Equations (13) and (14).
Typically, the mole fraction of S03 in SO is 0.02.86
.A.
After introducing the mole fraction of S02 oxidized to S03
^YS03) lnto Equation (13) we obtain 'Equation 14:
X = 25° x /X 0.6 Btu x IP"A . , N
XS03 £ x Xs — ] (1*0
ash \ S03 I
Equation (14) is plotted in Figure 66 for various sulfur
contents in coal at 9% ash in coal and 2% S03 in SO
Similar plots could be prepared for different coal ash
contents and S02-to-S03 conversions.
The band between 9,600 and 11,700 Btu's per Ib heating value
represents the overlap between western and non-western coal
average values derived from Table 27. The ceiling limits
for sulfur content in ash of western and non-western coals
were obtained from Table 53. These limits indicate that
a maximum of 10$ sulfur in coal (as S03) can be retained
by non-western coals and 27$ sulfur in coal (S03) can be
retained by western coals. The example below illustrates
the use of Figure 66.
6Welty, A. B. Fundamentals of Sulfur Oxide Removal from
Stack Gases. Esso Research and Engineering Company (For
presentation at the 63rd Annual Meeting of the Air Pollut-i
Control Association, St. Louis, Missouri, June 14-18 1970)
250
-------
WESTERN MAXIMUM SULFUR IN ASH CEILING
WESTERN MAXIMUM SULFUR IN ASH CEILING*
7000
8000
10,000 11,000
HEATING VALUE, Btu/lb
12.000
13.000
Figure 66. Minimum sulfur retention required in
ash to meet S0v standard of 1.2 Ib SOx/106Btu
A
-------
The minimum sulfur retention in ash (XSQ ) for western coal
with 8000 Btu/lb (as fired) and 1.0% sulfur in order to
be in compliance with the present standard is Ik.3% (point A)
For 12,000 Btu/lb (as fired) non-western coal with 1.3%
sulfur the value is 15.6? (point B). However, the standard
will most probably not be met as the maximum ceiling for
non-western coals is 10% as indicated by the heavy horizontal
line.
Figure 66 indicates that non-western coals with 9% ash
probably will not meet the standard if they contain more
than 1.035 sulfur. Western coals will probably not meet
standard if they contain more than 1.3% sulfur. Other
families of curves should be prepared and consulted for
coals with ash values different from the 9% value used in
Figure 66.
A laboratory check on the "as-fired" coal for % sulfur
retention in ash (Xso ) is then made to determine if the
actual value is above or below the minimum value obtained
from Equation Hi. This ultimately indicates the coal's
potential to meet the sulfur emission standard. The sulfur
retention in ash can routinely be determined, for example,
by a method outlined by the American Society of Testing
Materials. This method, ASTM D1757-62, gravimetrically
determines sulfur (as S03) in coal ash via barium sulfate
precipitation.87
87Anon. Standard Method of Test for Sulfur in Coal Ash
ASTM D1757-62 from Annual Book of ASTM Standards - Part 1Q-
Gaseous Fuels; Coal and Coke, American Society for Testing
and Materials, Philadelphia, Pennsylvania, 1972, pp. 260-261
252
-------
It must be realized that Equation CU) (and Figure 66)
should be interpreted solely as a guideline as it has
not been experimentally verified. It is proposed that the
relationship be verified by compiling information on sulfur
content of coal (X )i sulfur content of ash (XSQ ) coal
heating value (Btu) , ash content of coal (xash^s and sulf>ur
emissions through the stack (s*stack)-
The significance of these variables and their influence on
the accuracy of SO emission determination must be examined,
A.
The data for Equation (14) may be largely available through
boiler operator records as well as EPA files. Upon veri-
fication the relationship may aid in selection of proper
substitute fuel and the necessary modifications to the
boiler in order for it to comply with the sulfur emission
standard.
253
-------
SECTION 6
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255
-------
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256
-------
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257
-------
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258
-------
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•(Referenced material used with permission of McGraw-
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259
-------
66-
61. Duncan, L. J., E. L. Keitz, and E. P. Krajeski
Selected Characteristics of Hazardous Pollutant-
May 1973. The Mitre Corporation. EPA Pro?ec?
095A. Contract No. 68-01-0/138. 331 p/roject
62. Locklin, D.W., H. H. Krame, A. A. Putnam, et al Design
Trends and Operating Problems in Combustion Modification
of Industrial Boilers. Environmental Protection AgencT
Technology Series EPA-650/2-7^-032, April 1974? 168 p.
63. Johnson, A. J., and G. H. Auth. Fuels and Combustion
Handbook. New York, McGraw-Hill Book Compan^ Inc
1951, pp. 781 756. Copyright, 1951, by the McGra
Bo°o°k CC~: InC" US6d W"h P^Bslon of
64. Hollander, H. I. Another Look at the Traveling Grate
Stoker. University of Kentucky. (Presented at The
Industrial Coal Confer^nc-A T.O-VT v.n.-i-^v, v«_.i..._i___
Anr-n i m£c N C°nference. Lexington, Kentucky,
nprii i, 1905.; up.
65. Roberson J. E. Selection and Sizing of Coal Burning;
Equipment. Power Engineering. 42-45, October 1Q?4
( nei PT^F'nr'p'H mo +- Q-KI-I •*. -\ ,,^^j ..jj-i. ,__ . . _ ^ ' '
permission of Technical
67. Barrett, R. E., S. E. Miller and D. W. Locklin. Field
Investigation of Emissions from Combustion Equipment for
Space Heating. Battelle Columbus Laboratories EPA
Contract No. 68-02-0251. June 1973. 140 p.
68' Mo^dS\TC> v' ,Bollers-Types, Characteristics, and Punc
tions. New York, P. W. Dodge Corporation. 1971. 559 p7
69. Anon. Steam/Its Generation and Use. 37th Edition w^,
York Babcock and Wilcox Company, 1963 567 p ?Refe?
enced material used with permission of Babcock & WiJcoxT)
70. Technology and Use of Lignite. Proceedings: Bureau of
6
p io u Grand Porks' North Dakota,
8471 I970 aU °f M±neS Information Circular.
71. Garner L. J. The Formation of Boiler Deposits from tn
" Brown coals- J- °
260
-------
72. Holyoak, R. H. Burning Western Coals in Northern
Illinois. (Paper presented to the Fuels Division of
the American Society of Mechanical Engineers at the
Winter Annual Meeting, Detroit, Michigan, November 11-15,
1973.) 9 P.
73. White, H. J. Resistivity Problems in Electrostatic Pre-
cipitation. Journal of the Air Pollution Control
Association. 24(4):313-338, April 1974. (Referenced
material used with permission of Air Pollution Control
Association.)
74. McKinney, W. Tennessee Valley Authority, Division of
Power Production. Personal Communication.
75. Anon. Water Resources Research Institutes of Wyoming
Montana and North Dakota. Coal-Energy Development in
the Northern Great Plains. Laramie, Wyoming. NTIS
Publication PB-231560, October 1973- 114 p.
76. Paone, J., J. L. Morning, and L. Giorgetti. Land
Utilization and Reclamation in the Mining Industry,
1930-71. Bureau of Mines Information Circular. 8642.
1974. 61 p.
77. Anon. Environmental Pollution and Control. NTIS
Weekly Government Abstracts, p. 363, August 19, 1974.
78. Aldon, E. P., 0. D. Knipe, and G. Garcia. Revegetating
Devastated Sites in New Mexico with Western Wheatgrass
Transplants. Rocky Mountain Forest and Range Experi-
ment Station. Research Note RM-243. June 1973. 3 p.
79. Aldon, E. P., and H. W. Springfield. Revegetating Coal
Mine Spoils in New Mexico. Rocky Mountain Forest and
Range Experiment Station. Research Note RM-245. June
1973- 4 p.
80. Rulli, J. F. Reclamation at Big Horn Mine. Mining
Congress Journal 47:41-44, June 1971.
81. Bishop, P. 'Environmentalism' - Creating Crunch on
Coal Industry. Mining Congress Journal. 59:111,
February 1973.
82. Geer, M. R. Disposal of Solid Wastes from Coal Mining
in Washington, Oregon and Montana. Bureau of Mines
Information Circular. 8430. 1969. 39 p.
261
-------
83. Khan, Ii. A. EPA Stack Gas Scrubbing, P0908 Data
Preparation and Cost Analysis System. Systems and
Users Manual M. W Kellogg Company. EPA Contract
Nos. CPA 70-68 and 68-02-1308. January 1974.
84. National Emissions Data System (NEDS). Computer File
Listing of Condensed Point Sources for Utility
May 15, *
85. Cuffe, S. T. and R. W. Gerstle. Emissions from Coal-
Fired Power Plants: A Comprehensive Summary. National
Air Pollution Control Administration. 1967. 27 p.
86. Welty, A. B. Fundamentals of Sulfur Oxide Removal
from Stack Gases. Esso Research and Engineering Co
(For presentation at the 63rd annual meeting of the'
BOclatlon- 3t ' Louls> Missouri.
87. Anon. Standard Method of Test for Sulfur in Coal Ash
ASTM Standards - Part 19: Gaseous Fuels; Coal and "
Coke, American Society for Testing and Materials
Philadelphia, Pennsylvania, 1972. 470 p.
88. Noble, E. A. Mineral and Water Resources of North
Dakota, Bulletin 63, North Dakota Geological Survey in
Collaboration with the U.S. Geological Survey u S
Government Printing Office, 1973. 251 p. ' '
89. Coal Age, McGraw-Hill Publishing Co., Vol 79 No S
May 1974. 76-122 p.* ' '*' ' 5>
90. Anon. Coal Resources of Wyoming, Bulletin 8l, u.S Ger>
logical Survey, U.S. Government Printing Office, 1950.
91. Anon. Washability Examinations of Core Samples of San
Juan Basin Coals, New Mexico and Colorado, Report of
Investigations 7608 Bureau of Mines, 1972.
92. Read C. B., R. T. Duffner, G. H. Wood, and A. D. Zapn
Coal Resources of New Mexico, U.S. Geological Survey '
Bulletin 89, U.S. Government Printing Office, 1950.
93. Anon. Coal Resources of Colorado, U.S. Geological .„•--
Circular 1072-C, U.S. Government Printing Office, 1959??*
*(Referenced material used with permission of McGraw-Hill
Book Company.) x
262
-------
94. Mat son, R. E. and J. W. Blumer, Quality and Reserves
of Strippable Coal, Selected Deposits, Southeastern
Montana, Montana Bureau of Mines and Geology Bulletin
91, Montana College of Mineral Science and Technology,
95. Various. Coal Age, Western Coal Edition, Vol. 78
No. 5, McGraw-Hill Publishing Co., Mid-April 1973.
57-212 p.
96. Doelling, H. H., Central Utah Coal Fields, Monograph
Series No. 3 Utah Geological and Mineralogical
Survey, University of Utah, 1972. 571 p.
97. Doelling, H. H. and R. L. Graham, Eastern and Northern
Utah Coal Fields, Monograph Series No. 2, Utah
Geological and Mineralogical Survey, University of
Utah, 1972. 411 p.
98.. Doelling, H. H. and R. L. Graham, Southwestern Utah
Coal Fields, Monograph Series No. 1, Utah Geological
and Mineralogical Survey, University of Utah, 1972.
333 P.
99. Anon. Geology and Coal Resources of the Livingston
Coal Field, Gallatin and Park Counties Montana,
Montana Bureau of Mines and Geology, Montana College
of Mineral Science and Technology. 1966.
100. Livingston, V. E.,. Energy Resources of Washington,
State of Washington Department of Natural Resources,
Division of Geology and Earth Resources, Information
Circular No. 50, 1974. 158 p.
101. Walters, J. G., C. Ortuglio, and J. Glanezer, Yields
and Analyses of Tars and Light Oils from Carbonization
of U.S. Coals, BuMines Bulletin 643, 1967, 91 p.
102. Geology and Fuel Resources of the Mesa Verde Area,
Montezuma and La Plata counties, U.S. Geological Survey
No. 1072-M, 1959-
103. Gilmour, E. H. and G. G. Dahl Jr., Montana Coal
Analyses, State of Montana Bureau of Mines and Geology
Special Publication 43, 1967, 19 p.
104. Anon. Analyses of Wyoming Coals. Bureau of Mines
Technical Paper 484, 1931, 77 p.
263
-------
APPENDIX A
WESTERN COAL RESERVES BY FIELD
265
-------
Table A-l represents a compilation of reproduced data
available from open file literature. The data is organized
by coalfield or deposit, both terms being synonymous. The
overburden thickness categories represent the categories of
the original data. No attempt has been made to subtract
coal production for the years following the estimate. In
the majority of cases the individual tonnage figures have
not been distorted by additions or averages from several
sources. The specific measured, indicated, measured and
indicated, and inferred categories are as defined in
Section 3.1.
26?
-------
Table A-l. COAL RESERVES BY OVERBURDEN THICKNESSl>9>88~l°°
(millions of short tons @ feet of overburden)
State, Region,
Deposit and County(s)
Black Mesa
(Navajo, Apache,
Coconino)
0-200
0-2000
0-200 Total
0-2000 Total
Measured
Arizona - Bla
—
—
Indicated
ck Mesa Regl
—
—
Measured and
Indicated
on1
1,000
1,000
Colorado - San Juan Region1 >91 > 93
Cortez
(Montezuma)
0-200
150-250
0-3000
Nucla-Naturita
(Montrose)
0-3000
Durango*
• (Archuleto, LaPlata)
0-3000
3000-6000
Book Cliffs
(Garfield)
0-3000
3000-6000
Grand Mesa
(Delta)
0-3000
3000-6000
Tongue Mesa
(Delta)
0-300
0-6000
Somerset
(Gunnlson, Delta)
0-3000
3000-6000
Crested Butte
(Gunnlson)
0-3000
3000-6000
13.1
__
—
~
~
~
_ —
9,634
Colorado - Uinta Region1 »8»93
--
~
—
—
—
—
~
~
—
—
2,293
1,569
—
3,3^8
244
Inferred
20,000
20,000
115.2
29.5
2.20
1, 489.311
11,080
5,200
1,300
3,600
3,086
4,000
2,354.94
4,000
2,190
2,500
1,000
320
"Durango field = "hog back" •*• Mesa Verde + Pagosa Springs
269
-------
Table A-l (continued). COAL RKSKHVES
BY OVERBURDEN THICKNESS1'9'88-100
(millions of short tons @ feet of overburden)
State, Region,
Deposit and County(s)
Measured
Indicated
Measured arid
Indicated
Inferred
Carbondale
(Garfleld)
0-200
0-3000
3000-6000
Grand Hogback
(Garfield)
0-3000
3000-6000
Danforth Hi:Is
(Rio Blanco)
0-3000
3000-6000
Lower White River
(Rio Blanco)
0-3000
3000-6000
Yampa
(Routt)
0-3000
Walsenburg
(Huerfano)
0-200
Trinidad
(Los Anlmas)
0-3000
3000-6000
Canon City
(Fremont)
0-200
0-3000
South Park
(Park)
0-3000
North Park
(Jackson)
3000-600D
Middle Park
(Grand)
Colorado Ulnta Region (eont.)
~
—
1,136-
885
7,851
Colorado - Green River Region1»93
Colorado - Raton Basin Region1
Colorado - Canon City Region1'93
Colorado - South Park Region1'93
1,870
2,200
760
1,150
560
2,100
31,016.1(3
2,500
79,207
11,181)
237
217
295
92.5
25,000
No minable Beams
270
-------
Table A-l (continued). COAL RESERVES
BY OVERBURDEN THICKNESS1»9>88~1°°
(millions of short tons @ feet of overburden)
State, Region,
Deposit and County(s)
Measured
Indicated
Measured and
Indicated
Inferred
Colorado - Denver Basin1
Colorado Springs
(El Paso, Elbert,
Douglaa)
0-1000
Boulder Weld
(Weld, Jefferson,
Boulder, Denver,
Arapahoe)
0-1000
0-200 Total
150-250 Total
0-300 Total
0-3000 Total
3000-6000 Total
0-1000 Total
0-6000 Total
Decker
(Big Horn)
0-250
0-200
Hanging Women Creek
(Big Horn, Rosebud,
Powder River)
0-150
0-1000
Moorhead
(Powder River)
0-150
0-200
Roland
(Big Horn)
0-100
0-200
Squirrel Creek
(Big Horn)
0-150
0-200
Upper Rosebud
(Rosebud)
0-200
Burney
(Rosebud)
0-150
0-200
13.1
26,963
Montana - Fort Union Region1 >9I<
2,701.25
1,979.23
218.04
133.11
180.55
16,860
25,610
3,692.2
29.5
2,351.9
113,562.5
17,802
12,170
1,000
2,239.99
1,917
3,099
1,979
315
130
220
321
271
-------
Table A-l (continued). COAL RESERVES
BY OVERBURDEN THICKNESS*»9>88-1o0
(millions of nhort tons @ feet of overburden)
State, Region
Deposit and County(s)
Measured I Indicated
Measured and
Indicated
Canyon Creek
(Rosebud)
0-200
0-250
Poker Jim O'Dell
(Rosebud)
0-200
0-250
Otter Creek
(Powder River)
0-200
0-250
Ashland
(Powder)
1 0-200
0-250
Cook Creek
(Powder River)
0-200
Beaver Creek
(Powder River)
0-150
0-200
Liscorn Creek
(Custer)
0-200
Miller-Oreenleaf Creek
l
Montana - Fort Union Region (cont.)
1,950.11
938.07
2,075.55
3,053.69
627.1)9"
Inferred
200
770
1,011
2,595
53
160
75
vnuaeuua;
0-150
0-200
Sweeney - Snyder Creek
(Rosebud)
0-150
0-200
Colstrlp
(Rosebud)
0-150
0-200
Sarpy Creek
(Treasure, Big Horn)
0-200
Fire Creek**
(Powder River)
0-200
~
—
—
™
153.71
~™
326.33
~~
1,139.26
~~
— —
71.7
__
— —
—
— —
—
— —
— —
--
_.
312
— —
312
__
1,110
' 1,500
lo*»*
*»Pinto Creek + Fire Creek deposits
***Pire Creek only
272
-------
Table A-l (continued). COAL RESERVES
BY OVERBURDEN THICKNESS1'9'88-100
(millions of short tons % feet of overburden)
State, Region,
Deposit and County(s)
Measured
Montana Port Unio
Upper Cache Creek
(Powder River)
0-200
Lower Cache Creek
(Powder River)
0-200
Sonnette
(Powder River)
100-150
0-200
Pumpkin Creek
(Powder River)
0-200
0-250
Broadus
(Powder River)
0-150
0-200
Sand Creek
(Custer, Powder River)
0-150
0-200
Poster Creek
(Custer)
0-120
Pine Hills
(Custer)
0-150
0-200
Lame Jones
(Pallon)
0-200
East Moorhead
(Powder River)
0-150
0-200
Knowlton
(Custer)
0-150
0-200
Lamesteer
(Wibaux)
0-200
..
—
::
~
~
—
~
__
~
~
__
Indicated
n Region (c<
39-55
10.51
908.63
2.H26.50
739.82
267.31
193.87
__
525.21
867.82
__
Measured and
Indicated
mt .)
_
--
—
~
~
_ _
—
__
—
—
__
Inferred
no
10
183.06
206
1,900
737
278
1,190
86.09
280
150
511
798
35
273
-------
Table A-l (continued). COAL RESERVES
BY OVERBURDEN THICKNESS1.9,88-100
(millions of short tons @ feet of overburden)
State, Region,
Deposit and County (a]
HSnt
Poker Jim Lookout
(Powder River, Rosabud)
0-200
Redwater River
(McCone)
0-200
Weldon-Timber Creek
(MoCone)
0-200
Wibaux
(Wibaux)
0-200
Little Beaver
(Wibaux)
0-200
Four Buttes
(Wibaux)
0-200
Hodges
(Dawson)
0-200
Griffith Creek
(Daws on)
0-200
Smith-Dry Creek
(Richland, Wilbaux)
0-200
0' Brian - Alkalie Creek
(Richland)
0-200
Breezy Flat
(Richland)
0-200
Burns Creek
(Dawson)
0-200
N.F. Thirteen Mile Creek
(Dawson)
0-200
Pox Lake
(Richland)
0-200
Measured
sna - Fort I
„
..
..
__
_
..
..
..
..
_
_
Indlcate-l
nlon Rep.lon
872.65
_
_
_
..
_
..
..
_
Measured and
Indicated
_
..
..
_
_
..
..
Inferred
573
642
72t
613
131
91
10
10
150
150
200
200
325
H6
274
-------
Table A-l (continued). COAL RESERVES
BY OVERBURDEN THICKNESS1'9'88-1.00
(millions of short tons @ feet of overburden)
Deposit and County (s)
Measured
Indicated
Montana - Fort Union Reeion
Lane
(Rlchland)
0-200
Carrol
(Rlchland, Dawson)
0-200
Port Kipp
(Roosevelt)
0-200
Lanark
(Roosevelt)
0-200
Medicine Lake
(Sheridan)
0-200
Reserve
(Sheridan)
0-200
Coal -Ridge
(Sheridan)
0-200
Cheyene Meadows
(Rosebud),
Little Wolf
(Big Horn)
0-200
Jeans Pork
(Big Horn)
0-200
Wolf Mountain
(Big Horn)
0-200
Deer Creek
(Big Horn)
0-150
Kirby
(Big Horn)
0-200
West Moorhead
(•Powder River)
0-150
..
—
—
—
—
—
__
—
—
—
__
__
__
—
__
__.
__
-—
__
._
—
_ «
— _
195.65
1,683.01
1,971.12
Measured and
Indicated
(cont . )
—
—
Inferred
561
315
331
100
58
216
150
1,200
311
90
1,922
275
-------
Table A-l (continued). COAL RESERVES
BY OVERBURDEN THICKNESS1>9>88-1°°
(millions of short tons % feet of overburden)
State, Region,
Deposit .and County(s)
Measured
Indicated
Measured and
Indicated
Inferred
Montana - Fort Union Region (cent.)
Little Pumpkin Creek
(Powder River)
0-100
Home Creek
(Powder River)
0-150
Diamond Butto*
(Powder River)
0-150
Yager Butte
(Powder River)
0-150
Bull Mountain
(Mussellshell,
Yellowstone)
Carpenter Creek
(Mussellshell)
0-200
Charter
(Mussellshell)
0-200
Red Lodge
(Carbon, Stlllwater)
Brldger
(Carbon)
Silvertip
(Carbon)
Stillwater
—
—
"
~
215.83
217.21
1,383.66
1,187.88
-
-
-
-
Montana - Bull Mountain Basin1
50
60
Montana - Red Lodge Region1
Very small amount present and minable
Very small amount present and minable
Very small amount present and minable
(Stlllwater)
Montana
Great Falls
(Cascade)
0-200
Lewlston
(Judith, Fergus)
Very small amount present and
- Great Falls/Lewiaton Region9 •9't
?
..
?
815
?
ralnable
1,027
?
"Diamond Butte + Goodspesd Butte + Fire Ouleh
276
-------
Table A-l (continued). COAL RESERVES
BY OVERBURDEN THICKNESS1>9>88-100
(millions of short tons @ feet of overburden)
State, Region,
Deposit and County(s)
Measured
Indicated
Measured and
Indicated
Inferred
Montana - Electric Field Region1
Electric
(Park)
Montana - Livingston/Trail Creek Region"
Livingston - Trail Creek
(Gallatln, Park)
0-3000
Lombard
(Gallatin, Broadwater)
Plathead
(Plathead)
Unnamed Fields
(Granite)
0-100 Totals
0-150 Totals
0-200 Totals
0-250 Totals
0-1000 Totals
0-3000 Totals
2H5.809
55.696
Montana - Lombard Region1
Montana - Flathead Region1
Very small amount present and mlnable
'
—
--
—
133.8
15,994.1
7,962.7
6,067.3
81
24
1,276.1
26,737
4,139.9
3,099
55.7
New Mexico - San Juan Region1»91»92
Prultland
(San Juan)
0-150
150-250
NavaJ o
(San Juan)
0-150
150-250
Bisti
(San Juan)
0-150
150-250
Star Lake
(San Juan, Mckinley)
0-150
150-250
Baker Creek
(San Juan)
Hogback
(San Juan)
93.0
65.0
--
;;
No st
~
—
~
rippable, bi
—
1.02D. 7
1,352.8
--
it some under gr
—
958.0
912.0
365.0
270.0
Dund reserves
No strippable, but some underground reserves
277
-------
Table A-l (continued). COAL RESERVES
BY OVERBURDEN THICKNESS1»9>88-100
(millions of short tons % feet of overburden)
Deposit and County(a)
Measured
Indicated
Measured and
Indicated
Inferred
New
Mexico - San Juan Region1>91'
Toadlena
(San Juan)
Newcomb
(San Juan)
0-150
150-250
Chaco Canyon
(San Juan)
0-150
San Mateo
(Mckinley)
0-150
Standing Rock
(Mckinley)
0-150
150-250
Zuni
(Mckinley)
0-150
South Mount Taylor
(Valencia)
0-1000
La Ventana
(Sandoval)
0-150
Rio Puerco
(Sandoval)
Una del Qato
(Sandoval)
0-1000
1000-2000
2000-3000
Sandoval County
0-1000
1000-2000
2000-3000
Rio Arriba County
(Includes Monera, and
Tlerra Amarilla fields)
0-1000
1000-2000
2000-3000
2.9
No strlppable, but some underground reserves
78.5
6.3
31.0
21.2
63.5
75.0
6.2
278.1
Mined for local use only
0.6 7.0
5.7
3.2
67.5 2614.1
51.8
2.5
12.9
38.8
15.0
0.5
0.2
0.1
1,008.6
1,958.9
1,798.9
180.1
262.1
2,251.2
278
-------
Table A-l (continued). COAL RESERVES
BY OVERBURDEN THICKNESS1'9*88-100
(millions of short tons @ feet of overburden)
State, Region,
Deposit and County (s)
New Me
Mcklnley County
(Includes Gallup, and
Crownpoint fields)
0-1000
1000-2000
2000-3000
San Juan County
0-1000
1000-2000
2000-3000
Measured
xlco - San <
233.8
501.5
Indicated
Juan Region (
239.1
1,062.5
166.5
13.6
Measured and
Indicated
cont . )
__
—
New Mexico - Raton Region92
Raton
(Colfax)
0-1000
1000-2000
2000-3000
567.9
1,189.6
107.0
New Mexico - Cerrllos Reel
Cerrilos
(Santa Pe)
0-1000
1000-2000
Tijeras
(Bernalillo)
0-1000
Carthage and Jornado
del Muerto
(Socorra)
0-1000
N
Sierra Blanca
(Lincoln, and Otero)
0-1000
1000-2000
2000-3000 ',
8.0
0.1
New Mexico
0.1
New Mexico
19.7
11.3
3.2
- Tiler as92
1.2
- CarthaKe92
11.3
;w Mexico - Sierra Blanc
3.3
8.0
—
Dn92
—
1.7
a92
~
Inferred
10,036.1
1,818.9
836.2
7,771.8
11,327.6
11,591.1
703.2
1,739.2
102.1
0.7
25.6
758.3
558.7
315.7
279
-------
Table A-l (continued). COAL RESERVES
BY OVERBURDEN THICKNESSl»9>88-100
(millions of short tons @ feet of overburden)
State, Region,
Deposit and County (s)
N
Datil Mountain
(Valencia, Catron,
and Socorro)
0-1000
1000-2000
0-150 Totals
150-250 Totals
0-1000 Totals
1000-2000 Totals
2000-3000 Totals
N
Noonan-Kincaid
(Burke)
0-200
Niobe
(Ward, and Burke)
0-200
Avooa
(Williams)
0-200
M. and M.
(Williams)
0-200
Velva
(Ward)
0-200
Measured
ew Mexico -
93.0
65.0
1,121.5
0.4
Indicated
Datll Mounta
2,839.2
337.2
19.3
.le.icured and
Indicated
In"
1 ,02'(.7
1,352.8
'1.7
3rth Dakota - Northwestern88
__
..
North Dakota - Southwester
Washburn
(Mclean) ,
0-200
Winton
(Burlelgh)
0-200
Renner's Cove
(Mercer)
0-200
Hazen
(Mercer)
Beulah-Zap
(Mercer)
0-200
Stanton
(Mercer, and Oliver)
0-200
_
—
~
__
—
15
116
380
100
5
n89
30
15
78
71
380
21
Inferred
737.3
582.9
1,538.4
1,263.3
21,775.3
18,304.4
17,201.6
280
-------
Table A-l (continued). COAL RESERVES
BY OVERBURDEN THICKNESS1»9>88~l0o
(millions of short tons @ feet of overburden)
State, Region,
Deposit and County(s)
Nor1
Center
(Oliver)
0-200
Dunn Center
(Dunn)
0-200
Dickinson
(Billings, Dunn,
and Stark)
0-200
Beach
(Golden Valley)
0-200
Bowman - Qascoyne
(Slope, and Bowman)
0-200
New Leipzig
(Grant, and Hettlnger)
0-200
0-200 Totals
Coos Bay
(Coos)
0-1500
Eden Ridge
(Coos, and Curry)
Measured
;h Dakota -
__
__
__
__
—
Indicated
Southwester
..
— —
__
__
—
Oregon - Coos Bay9
23.76
27.00
Oregon - Eden Ridge9
Relatively inaccessib
Measured and
Indicated
n (cont.)
253
1,500
798
1(50
1,372
105
5,719
le
*
Inferred
_
..
..
—
15.11
Rogue River
Eckley
John Day
Little exploration, many impurities in the coal
No production - many flats and folds in coal beds
Coal Impure - low Btu value, beds highly faulted
0-1500 Totals
• Sout
Upper Northwest
0-1000
0-1000 Totals
23.76
h Dakota -
~
27.00
Upper Northw
:;
est"
~
15.11
1,000 to 1,500
1,000
281
-------
Table A-l (continued). COAL RESERVES
BY OVERBURDEN THICKNESS1»9,88-1o0
(millions of short tons @ feet of overburden)
State, Reeion
Deposit and County(s)
• Measured and
Indicated Indicated
Alton
(Kane & Oarfield)
0-200
0-1000
1000-3000
Kaiparowlts Plateau
(Kane & Oarfield)
0-3000
Kolob & Harmony
(Iran, Washington and Kane)
i
Utah - Southwestern98
Mt. Pleasant
(Sanpete)
0-1000
Sallna Canyon
(Sevler)
2000-3000
Sterling
(Sanpete)
2000-3000
Wales
(Sanpete)
2000-3000
Waaatch Plateau
(Carbon, Emery, Sanpete
and Sevier)
0-3000
Book Cliff
(Carbon and Emery)
0-3000
Emery
(Emery and Sevier)
0-3000
Utah - Central9*
249.1
Utah - Eastern t Northern'
Vernal
(Ulntah)
0-3000
POO
1,000
900
15,200
2,000
85
12
3,500
1,000
282
-------
Table A-l (continued). COAL RESERVES
BY OVERBURDEN THICKNESS1'9'88"100
(millions of short tons @ feet of overburden)
State, Region
Deposit and County (s)
Measured
Utah - Eastern
Henry Mts.
(Wayne and Oarfield)
0-200
0-3000
Sego
(Ulntah and Grand)
0-3000
LaSal - Sari Juan
(Grand San Juan)
Tabby Mts.
(Wasatch and Duchesne)
0-3000
Coalville
(Summit)
0-3000
Henrys Pork
(Uintah)
Goose Creek
(Box Elder)
Lost Creek
(Morgan)
0-1000
0-200 Totals
0-1000 Totals
1000-3000 Totals
O-200'O Totals
2000-3000 Totals
0-3000 Totals
~
—
No reserve
__
Low oocurr
Indicated
& Northern
~
—
__
Measured and
Indicated
(cont . )
—
_
s over H feet thick
_..
..
ence of coa
L
Low occurrence of coal
Low occurr
—
ence of coa
219.1
.
—
Washington - Kelso Castle Rock Area1
Kelso-Castle Rock
(Cowlitz, and Lewis)
0-3000
Roslyn
(Klttltas)
0-3000
__
Washington - Roslvn1'100
—
—
....
Inferred
70
160.9
293.6
231
186
1.1
270
1,001.1
900
2,000
99
21,496.5
150
282
283
-------
Table A-l (continued). COAL RESERVES
BY OVERBURDEN THICKNESS1•9»88-1o0
(millions of short tons @ feet of overburden)
State, Region,
Deposit and County(s)
Wash
Taneum - Manastash
(Kittitas)
0-3000
Measured
ington - Ta
Indicated
neum Manastas
Washington - Eastern Lewis Cou
Eastern Lewis County
(Lewis)
0-3000
_
Measured and
Indicated
hl tlOO
ntyl,100
Washington - Isaquat Grand RldKe1'100
Taylor
(King)
0-3000
New Castle/Grand Ridge
(King)
0-3000
Cedar Mountain
(King)
0-3000
Renton Area
(King)
0-3000
Tiger Mountain
(King)
0-3000
Nlblook
(King)
0-3000
..
_
__
_-
__
__
«
__
..
..
..
Washington - Green River1'100
Green River
(King)
0-3000
Also listed as Black Dia
raond - Rave
nadale with "
60 tons.
Washington - Wilkeson - Carbonado1'100
Wilkeaon - Carbonado
(Pierce)
0-3000
Washington - Watcom County1*100
Watcom County
(Whatoora)
0-3000
___
_ _
..
Inferred
10
1
18 '
616
67
55.5
9
3?
351.5
298
316
284
-------
Table A-l (continued). COAL RESERVES
BY OVERBURDEN THICKNESS1>9>88~1°0
(millions of short tons @ feet of overburden)
State, Region,
Deposit and County(s)
Measured
Indicated
Washington - Centralla - Chphm
Centralla-Chehalis
(Lewis and Thurston)
0-3000
""
Measured and
Indicated
1S1 ,95,100
~~
Washington - Fairfax - Ashford1 >95,ioo
Fairfax - Ashford
(Pierce)
0-3000
Washington - Morton1'100
Morton
(Lewis)
0-3000
—
—
Washington - SkaEit County Ar-pai'lOO
Skagit County
(Skaglt)
0-3000
0-3000 Totals
— —
--
—
— -
Wyoming - Powder River- Ras1n90
Spotted Horse
(Campbell and Sheridan)
0-3000
Sheridan
(Sheridan)
0-3000
Sussex
(Johnson)
0-3000
Gillette
(Converse)
0-3000
Powder River
(Campbell)
0-3000
Buffalo •,
(Johnson)
0-3000
Barber
(Johnson)
0-3000
—
397.81
—
—
830. 42
—
—
2,325.23
2,333.05
585.02
4,526.41
7,539.14
1,401. 80
405.17
~
—
—
—
—
—
—
Inferred
3,692
64.
. 440
507
6,945
3,541.48
13,567.49
"
233.44
10,238.35
17,196.61
1,380.76
1,134.72
285
-------
Table A-l (Gontinued). COAL RESERVES
BY OVERBURDEN THICKNESS1.^'88-100
(millions of short tons @ feet of overburden)
State, Region
Deposit and County (s)
Wyora:
Lost Spring
(Converse)
0-3000
Central Part of Basin
0-3000
Measure's
ng - Powder
IrHllcateti
River Basin
577.75
—
Measured and
Indicated
(cont . )
—
Wyoming - Hams Fork Region1*90
Kemmerer
(Lincoln)
0-3000
Grays River
(Lincoln)
0-3000
McDougal
(Tenton)
0-3000
Evanston
(Vinta)
a- 3000
731.12
_—
16.61
3.316-31*
— —
89.72
299-25
__
..
Wyoming - Bighorn Basin1 >90
Meeteetse
(Park)
0-3000
Oregon Basin
(Park)
0-3000
Gebo
(Hot Springs)
0-3000
Grass Creek
(Hot Springs)
0-3000
Silver Tip
(Park)
0-3000
Garland
(Park)
0-3300
Basin
(Bighorn)
0-3000
Southeastern
(Washakie)
C-3000
-_.
23.84
—
~
97.61
23.84
__
99-82
17.90
27.19
lU.Qlf
37.20
__
__
—
—
—
—
—
—
Inferred
307.71
9,717.08
360.87
0.68
10.75
15.20
35.10
—
1.93
1.65
10.56
3.2't
51.2'i
286
-------
Table A-l (continued). COAL RESERVES
BY OVERBURDEN THICKNESS1»9»88~l00
(mil Lions of short tons @ feet of overburden)
State, Region
Deposit and County(s)
Wyo
Muddy Creek
(Fremont)
0-3000
Pilot Buttc
(Fremont)
0-3000
Hudson
(Fremont )
0-3000
Alkali Butte
(Fremont)
0-3000
Ts. 33-34 N. , R96W
0-3000
Powder River
(Natrona)
0-3000
Measured
mlng - Wind
—
—
21.71
—
—
—
Indicated
River Baslr
42.50
0.36
37.26
85.73
208.11
176.86
WyominK - Black Hills Rf.pi
Cambria
(Weston)
0-3000
Skull Creek
(Weston)
0-3000
Sundance
(Cook)
0-3000
Aladdin
(Cook)
0-3000
11.88
—
0.56
0.59
WyominK - Green
Little Snake River
(Carbon)
0-3000
Great Divide Basin
Red Desert
(Sweetwater and Carbon)
0-3000
—
.
10.01
3.42
—
~
Rlver Regie
1,174.94
732.60
Measured and
Indicated
1,90
—
—
—
~
—
—
on1'90
—
—
—
—
nl,90
—
—
Inferred
__
__
3.77
299.36
— —
14.63
__.
__
763.99
547.28
287
-------
Table A-l (continued). COAL RESERVES
BY OVERBURDEN THICKNESS1'9'88-100
(millions of short ton:; i? feet of overburden)
State, Region
Deposit and County(s)
Wyo
Rock Springs
(Sweetwater)
0-3000
Measured
ming - Greer
1,531.:"*
Indicated
i Hlver Reglo
•j, 796. 86
Wyoming - Hanna Field Outcrop
Hanna Field
(Carbon)
0-3000
Rock Creek
(Albany)
0-3000
Wyo
Jackson Hole
(Teton)
0-3000
Wv_
Goshen Hole
(Goshen)
Has never been estimate
52.72
3,179.6?
Wyoming - Southeast Reg!
Tilni? - North
257.91
western Re.^l
..
Measured 'ind
Indicated
n (oont . )
'legion'0
on1
—
_
smlng - Southeastern Region1
1.
Wyoming - Fowde
Little Powder River
(Campbell)
0-3000
Pumpkin Buttea
(Campbell)
0-3000
Dry Cheyenne
(Converse)
0-3000
Glenrock
(Converse )
0-3000
0-3000 Totals
__
__
3.13
3,621.9
r River Basl
2,789. 21
1,125.06
132.85
272.99
<40,072.8
n9"
— —
__
—
__
~
Inferred
38 '(.62
t7.27
121.49
630.66
11,516.13
18.22
121.32
77,61(8.6
288
-------
Table A-l (continued). COAL
BY OVERBURDEN THICKNESS1'9
(millions of short tons @ feet of overburden)
RESERVES
, 88-100
State, Region
Deposit and County(s)
0-100 Totals
0-150 Totals
150-250 Totals
0-200 Totals
0-250 Totals
0-300 Totals
0-1000 Totals
1000-2000 Totals
0-2000 Totals
0-1500 Totals
1000-3000 Totals
0-3000 Totals
2000-3000 Totals
3000-6000 Totals
0-6000 Totals
Total all categories
Measured
All West
__
93
65
• 13.1
--
—
1,121.5
0.1
—
23-76
—
3,621.9
—
—
—
5,238.6
Indicated
-ern States
433.8
15,991.1
—
7,962.7
6,067.3
—
3,088.3
337.2
—
27
—
10,072.8
19-3
—
—
71,002.5
Measured and
Indicated
1,021.7
1,352.8
7,531
__
1.7
—
—
—
27,208.8
—
—
—
37,125
Inferred
2,811.5
1,292.8
30,699.2
1,139.9^
2,351 .9
69,315.1
18,301.1
22,000
15.11
900
219,708.3
17,300.6
17,802
1,000
170,677.1
289
-------
APPENDIX B
WESTERN COALFIELD DESCRIPTIONS
291
-------
The following Is a state-by-state compilation of character-
istics which define individual coalfields from a mining
operations viewpoint. Typical quantities described in this
section are:
1. Coalfield land area
2. Seam formation and thickness
3. Topographical layout
Jj. Strippable potential
5. Overburden characteristics
6. Overburden thickness
7. Mining problems
8. Mining activity to the present
The majority of information in this appendix is reproduced
directly from the literature or quoted in summary form.
A more comprehensive treatment of this subject can be found
in various state reports and the 19?4 Keystone Coal Manual.
Refer to appendices A, C and G to obtain further data on
individual coal deposits. Maps of the coalfields may be found
in section 3.1 of the text.
Arizona
The following quote from the Bureau of Mines describes
Arizona's strippable coal seams:
Commercial seams lie in the Dakota and Mesa Verde
formations of Cretaceous age. Seam thicknesses average
between 4 and 22 feet, and for the most part, coal
seams dip approximately 2°. Owing to the extreme
lenticularity of individual seams, difficulty is
encountered in seam correlation and estimation of the
volume of resource.2
293
-------
Peirce describes all major coal areas and rank.1 The Black
Mesa Number 1 and Number 2 mines are currently producing
strip coal.
Although there are minor occurrences elsewhere
Arizona's principal coal-bearing region is Black
Mesa, an area of approximately 3200 square miles in
the Colorado Plateau portion of northeastern
Arizona (Peirce and Wilt, 1970). Black Mesa is
largely in Navajo County and is totally within the
Jurisdiction of the Navajo and Hop! Indian tribes.
The Black Mesa Field, which contains Arizona's
only known viable coal reserves, is coincident
with the geomorphic feature called Black Mesa and
covers about 2.8% of the land area of the state.
The ranks of coals present in the Black Mesa Field
have been reported variously, the variations
ranging on either side of the line that separates
subbituminous from bituminous coal. Jones (1972)
states that Peabody's coal is bituminous and that
one of their mines will average, on a dry basis,
12,325 Btu or more. Peirce and Wilt (1970), after
summarizing all of the then available analyses, con-
cluded that the coals of the Black Mesa Field are
high volatile C bituminous. On the other hand,
the U.S. Bureau of Mines (1971) classed Arizona's
strippable reserves (actually Peabody's reserves)
in the Black Mesa coalfield as subbituminous.
294
-------
Colorado
A general coalfield description of. Colorado coalfields
is found below.2 In general Colorado coal must be deep
mined.
Six counties of eastern Colorado (Adams, Arapahoe,
Boulder, Elbert, El Paso, and Weld) in the Denver
Basin have production records back to 188?. De-
sultory small-scale mining took place some years
ago in underground and strip-mined areas where the
coalbed is near the surface. The coal seams are
lenticular and lignitic in some places about 15
miles east of Denver. These seams extend on a
southward trend through Adams, Arapahoe, and
Elbert counties. The most significant underground
and strip mine production (until the latest close-
down in 1963) was in the subbituminous coal near
the terminus of that southward trend at Prance-
ville. Here the coalbed flanks upward against the
Rock Mountain uplift in the Colorado Springs
coalfield of El Paso county.
Owing to the hard sandstone that envelopes some
Colorado coalbeds, particularly in the Western
Plateau province, cutoffs used were a maximum of
50 feet of overburden or a 10-to-l stripping ratio,
a minimum coalbed thickness of 5 feet, a minimum
of 12,000 Btu per pound of coal, and low sulfur
content.
295
-------
Individual Colorado coalfield descriptions are cited from
Hornbaker and Holt.1
Durango Field
The Menefee Formation coals are high volatile A
bituminous and high volatile B bituminous rank
and are of coking quality in structurally affected
areas near Durango. Only one of the four operating
mines in 1971 was a strip mine. The coal was
used for the Durango Electric Plant. 3'2" to
6'7" is the thickness of the coal. The deep mines
are 3,000 to 6,000 feet deep.
Book Cliffs Field
Some high volatile B bituminous coal exists but
most is high volatile C bituminous.
1. The "Anchor Seam" is 6'2" thick
2. The "Palisade Seam" is 2'8" to 9«4" thick
3- "Carbonera Seam" is 7'6" to 8'6"
Book Cliffs field occupies 800 square miles. One
mine was in operation in 1971.
Grand Mesa Field
The coal is subbituminous A to high volatile C
bituminous and is 4.5 to 14 feet thick. It occupies
550 square miles. Two mines were worked in 1971
one a strip mine.
296
-------
Tongue Mesa Field
Near the top of the mesa is a 900-foot thick coal-
bearing section with an easterly dip of 2 degrees.
The Cimarron seam is 8 to more than 40 feet thick.
The coal is subbituminous B and is difficult to
get to.
Somerset Field
The coal is high volatile B bituminous coal and
high volatile C bituminous, produced by 4 mines.
The field occupies 220 square miles.
1. Bowie Shale "lower group" coals:
6.5 to 17.7 feet
2. Paonia Shale "upper group" coals:
12 to 13 feet thick
Crested Butte Field
The coal is high volatile B bituminous and high
volatile C bituminous and is of good coking quality
with a thickness of 2 to 9 feet with a maximum
of 14 feet. There are 6 seams. The field is 240
square miles to depths of 6000 feet. One small
mine was in operation in 1972.
Carbondale Field
The southern half of the field is metamorphosed
to high volatile A bituminous coal and non-coking.
The seams are 4 to 11.5 feet thick. They cover
297
-------
165 square miles with depths up to 6,000 feet.
There were 4 mines operating in 1972.
Grand Hogback Field
The southern part is high volatile B bituminous
coal and the northern is high volatile C coal.
The seams range in thickness from 3.5 to 18 feet.
The field covers 165 square miles with coal at
6,000 feet.
Danforth Hills Field
The seams range in thickness from 4 to 34 feet
thick with high volatile C bituminous coal and
all of it is non-coking. The field covers 3^0
square miles to depths of 6,000 feet. No rail-
roads serve the area and development is limited.
One mine was worked in 1972.
Lower White River Field
Seams are 8 to 12 feet thick and are primarily
high volatile C bituminous coal. The field
occupies 930 square miles.
Yampa Field
Yampa Field is well serviced by railroads. The
seams are 3 to 23 feet thick and rank ranges from
high volatile C bituminous coal to anthracite coal,
The field is 1680 square miles and the deepest
298
-------
mine is 3,000 feet. Up to 70 mines have been in
operation, but only 7 were worked in 1972.
Walsenburg Field
The seams are 3 to 7 feet thick and are high
volatile B bituminous coal and high volatile C
bituminous coal, non-coking. The area of the
field is 220 square miles. The deepest mine
worked was 3,000 feet. Ninety mines have
operated in the area, the last in 1972.
Trinidad Field
The coal is high volatile A bituminous with some
high volatile B bituminous and all is cokeable.
The seams are 4 to 9 feet thick. The area is
890 square miles with the deepest mines at
3,000 feet. There have been Uli mines in 1U
minable seams.
Cannon City Field
The coal is high volatile C bituminous coal,
non-weathering, nonagglomerating and non-coking.
The seams are 3 to 10 feet thick. There are 16
seams but only 7 are of any commercial importance.
There have been 70 mines worked but only a few are
operational now. Some strip mining is done. Four
hundred fifty square miles of land is minable with
the deepest mine at 2,000 feet.
299
-------
South Park Field
The coal is subbituminous A and subbitumlnous B.
It covers an area of 20 square miles. NO reserve
estimates were performed below 3,000 feet. Some
mining was done around 1900. It was difficult
due to weathering and dips to 1*5°. There are
7 or 8 flooded old mines.
North Park Field
In the Northeastern part seams are 10 to 58 feet
thick. Dips range from 20° to 85°. In the south-
eastern part seams are about 20 feet thick with one
22 to 77 feet. Dips run from 10° to 20°. Eight
hundred square miles are minable down to depths of
3,000 feet. There are a few mines in the area.
Middle Park Field
Very limited exploration has revealed no minable
seams of coal but the possibility of appreciable
resources exists in an area of about 270 square
miles of the Middle Park Formation. There is no
satisfactory basis for an estimate of resources.
Colorado Springs Field
The seams range between 5 and 17 feet and are
subbituminous C coals. There is about 2,900
square miles of coal land. No mining is done
presently.
300
-------
Boulder-Weld Field
The seams are 4 to lH feet thick with subbituminous
B and C coal. Shaft mining predominates over drifts
or slopes. Depth of the shafts range from 250 to
450 feet. The field is 1525 square miles.
Montana
The Bureau of Mines considers Montana coals to be of major
importance in the development of the western coal industry,
A summary of general characteristics of Montana fields is
found below.2
Strippable deposits of lignite and subbituminous
coal in the eastern part of Montana lie in the Tongue
River member of the Tertiary Port Union Formation.
Most of the resources are in beds 20 to 30 feet in
thickness; however, seam thicknesses range upward
to 85 feet.
Matson describes the characteristics of individual coal-
fields.1 Coalfields cover about 35% of the land area of
the state of Montana.
Decker Coalfield
Three minable coal beds underlie the area. The
Anderson and Dietz coal beds range in thickness
from 20 to 89 feet. Ash content averages 3.5%
and sulfur content is 0.4*. The field covers
39.8 square miles.
301
-------
Hanging Women Creek Coalfield
Two beds are in this field. Anderson bed ranges
from 20 to 35 feet thick while Dietz is from 12
to 1H feet thick. Ash content is 6.H%. Sulfur
averages 0.3%. The field covers 122.2 square miles.
Moorhead Field
Three beds occupy this field. Anderson bed has a
thickness of Hi to 30 feet, Dietz bed ranges from
6 to 11 feet thick, and Canyon ranges from 7 to
25 feet thick. Ash content is 5.3*. Sulfur con-
tent is 0.3*. The field covers 77-3 miles.
Poker Jim Lookout Field
Anderson and Dietz beds range from 15-58 feet
thick. Ash is 5.7*. Sulfur content is 0.4*.
The field is 13.2 square miles.
Roland Field
The Roland bed is 10 feet thick. Ash content is
5.6%, and sulfur content is 0.3*. Roland field
covers 27.8 square miles.
Squirrel Creek Field
Roland bed is 10 feet thick. Ash content averages
5.6*. Sulfur averages 0.3*. Squirrel Creek field
covers 11.5 square miles.
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Upper Rosebud Field
This field contains the Smith, Anderson, Canyon,
and Wall coal beds. Anderson bed's thickness is
20 feet. Upper Rosebud Field covers 9.7 square
miles.
Birney Field
The Brewster-Arnold coal bed, which averages 18
feet in thickness, is in Birney Field. The field
covers 18.9 square miles.
Canyon Creek Field
The wall coal bed has a thickness of 60 feet in
the Canyon Creek area. Canyon Creek Field covers
about 4.4 square miles.
Poker Jim O'Dell Field
The Knoblock bed has two benches having a combined
thickness ranging from 10 to 40 feet. This field
covers 25.2 square miles.
Otter Creek Field
In this field, the Knoblock bed ranges from 20
to 60 feet in thickness. Otter Creek Field covers
31.7 square miles.
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Ashland Field
In the Ashland Field, the Knoblock bed ranges in
thickness from 25 to 70 feet. This field is 42.7
square miles in area.
Cook Creek Field
The Sawyer coal bed in this field has a thickness
ranging from 8 to 12 feet. Cook Creek Field covers
4.7 square miles.
Beaver Creek Field
In the Beaver Creek Field, the Knoblock bed ranges
from 12 to 22 feet in thickness. Beaver Creek
Field has an area of 8.3 square miles.
Liscom Creek Field
The Knoblock coal bed has an average thickness of
8 feet. The field covers 8.3 square miles.
Miller-Greenleaf Creek Field
The Knoblock coal bed is about 22 feet thick
and the Rosebud bed averages 12 feet thick. Mllier-
Greenleaf Creek Field covers 12.4 square miles.
Sweeney-Snyder Creek Field
The Terret coal bed averages 18 feet in thickness.
The field has an area of 16.4 square miles.
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Colstrip Field
Rosebud coal bed averages 25 feet in thickness
here. Colstrip Field covers an area of 51.3 square
miles.
Sarpy Creek Field
In Sarpy Creek Field are parts of the Rosebud and
McKay coal beds, each as much as 35 feet thick
with a minimum of 10 feet thick. Sarpy Creek
Field has an area of 66.2 square miles.
Fire Creek Field
Pawnee coal bed is 16 to 20 feet thick. Fire
Creek Field covers 2.0 square miles.
Upper Cache Creek Field
Pawnee bed averages 20 feet in thickness. The
field has an area of 1.7 square miles.
Lower Cache Creek Field
The Broadus coal bed has an average thickness of
12 feet. The field has an area of 0.7 square
miles.
Sonnette Field
Pawnee, average thickness of 20 feet, Cook, Sawyer,
and Ferry coal beds are in Sonnette. Sonnette is
9.1 square miles in area.
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Pumpkin Greek Field
Sawyer bed averages 30 feet in thickness. The
field covers 65.5 square miles.
Broadus Field
The Broadus bed ranges from 5-26 feet in thick-
ness. Broadus Field covers 29.5 square miles.
Sand Creek Field
The Knoblock coal bed has a thickness ranging
from 15 to 32 feet. Sand Creek Field has 9.3
square miles of area.
Foster Creek Field
The Knoblock bed is between 8 and 16 feet
thick. Foster Creek Field covers 90.6 square
miles.
Pine Hills Field
The Dominy coal bed has an average thickness of
17 feet. Pine Hills Field covers 14.1 square miles,
Lame Jones Field
The Dominy ranges in thickness from 6 to 10 feet.
Lame Jones has an area of 16.6 square miles.
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East Moorhead Field
The Cache bed ranges from 9 to 26 feet thick.
The field has an area of 25.0 square miles.
Knowlton Field
The Dominy coal bed ranges from 8 to 31 feet
in thickness. Knowlton has an area of 24.0
square miles.
Redwater River and Weldon-Timber Creek Field
S coal bed ranges in thickness from 8 to 12
feet. Redwater River covers 37.8 square miles
and Weldon-Timber Creek covers 40.0.
Bull Mountain Coalfield
The coal in this field is in the Tongue River
Member of the Ft. Union formation. The Tongue
River Member has a thickness of 1700 feet and
contains 26 persistent coal beds. Most of the
coal mined comes from the Roundup coal bed, which
is 500 feet above the base of the Tongue River
Member and is 4 to 6 feet thick. The Carpenter
bed, 5 to 8 feet thick, and the Mammoth bed, 5
to 14 feet thick in the Charter strippable field
have some potential.
Red Lodge Coalfield
The Fort Union beds dip steeply at Red lodge and
begin to flatten out at Bear Creek. The eight major
coal beds in the Red Lodge coal field range in
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thickness from 3-1/2 to 10 feet, and each has
produced some coal. The coal ranks as high-
volatile C bituminous. Closely related to the
Red Lodge coalfield are the Bridger, Silver-tip,
and Stillwater fields, but in those fields the*
coal is in the Eagle Sandstone. Late Cretaceous coal is
in the Bridger coalfield, only one bed 2-1/2
to 6 feet thick, is workable. This bed has been
mined in the Joliet, Promberg, and Bridger areas.
At the Silvertip field, two coal beds occur in
the Eagle Sandstone and have approximately the
same quality as the coal in the Bridger field.
Great Falls-Lewistown Coalfield
This field contains coal in the Morrison Formation
of Jurassic age. Coal is high-volatile B and C
bituminous. Thickness of coal is erratic with a
maximum of about 18 feet.
North Central Region
The coal in the North Central region is in the
Eagle Sandstone (Upper Cretaceous), and is ranked as
subbituminous. Coal is also found in the Judith River
Formation along the Missouri River, where the coal
beds range from 2-1/2 to 7 feet in thickness. The
rank and quality are similar to those of the coal
in the Eagle Sandstone, but most of the Judith
River coal is impure.
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Blackfoot-Valier Region
The coal in the Blackfoot-Valier field is in
the St. Mary River Formation and in the lower part
of the Two Medicine Formation both of (Upper
Cretaceous) age. The coal is relatively thin
in this area, ranging in thickness from 20 to
36 inches.
Electric Field
The Electric Coalfield occupies a small area in
the southwestern part of Park County. Thickness
of the coal ranges from 3 to 5 feet, and the
rank ranges from high-volatile A to low-volatile
bituminous, depending on location.
Livingston-Trail Creek Field
Livingston-Trail Creek field is in Gallatin and
Park counties. The three or four coal beds are
in Upper Cretaceous rocks and range from 2 to 5
feet in thickness. Rank of the coal ranges from
high-volatile A bituminous to C.
Lombard Field
The Lombard, in northern Gallatin county and
southern Broadwater county, is about 6 square
miles in area. Total thickness of coal is 6
feet. The coal is in the Morrison Formation.
It varies in rank in proportion to structural
deformation, but most of it is medium-volatile
B bituminous.
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Flathead Field
Coal In the Flathead field, a small area in the
northern part of Flathead county in an inter-
mountain basin, is in Tertiary strata. The coal
ranks as subbituminous and the maximum known
thickness is 3 feet.
Western Tertiary Fields
Numerous parts of the western Montana intermountain
basins contain coal in beds of diverse thickness
and areal extent. These coals are Tertiary in age
and generally rank as subbituminous. Thickness
as great as 25 feet has been reported.
New Mexico
A brief description of strippable coal reserves of New
Mexico as reported by the Bureau of Mines is found below.2
Strippable coal in New Mexico occurs as lenticular
deposits in the Menefee, Crevasse Canyon, and Fruit-
land Formations of Cretaceous age. The coal seams
dip gently eastward except at the extreme northern
and southwestern fringes of the basin where strata
are folded into prominent regional monoclines. Of
the coal-bearing formations, the Fruitland offers
the best prospects for abundant strippable coal.
The best coal in Crevasse Canyon Formation is near
Gallup where seams thicken and unite. Coal also
appears in the overlying Menefee Formation. Else-
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where coal seams in the Crevasse Canyon and
Menefee Formations are presumed to be thin, but
too little is known to say definitely where
strippable potential does or does not exist.
The following excerpts by Kottlowski and Shomaker describe
fields in the San Juan Basin region.1
The San Juan Basin Region is subdivided into 19
coalfields or areas covering over 26,000 square
miles in northeastern New Mexico.
Pruitland Field is currently being strip mined,
with seams averaging 16 feet with a maximum of
50 feet and an overburden of less than 250 feet.
The coal is high-volatile B bituminous coal and
high-volatile C bituminous coal.
Barker Creek. Hogback, and Toadlena Areas
Small underground mines have been operated
periodically for local use in the Hogback Field.
Multiple coal beds occur in the Menefee in the
Barker Creek Area. These are either involved in
the Hogback monocline, where the seams dip too
steeply to permit strip mining or they are overlain
by thick beds of the massive Cliff House Sandstone.
Thus, no strippable reserves have been calculated
for this area. Similar seams occur in the upper
and in the lower parts of the Menefee Formation
in the Hogback Field. Locally these beds thicken
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to 22 feet. The strata are structural to 38°.
Thus, no strlppable reserves were calculated. The
coals are typically high-volatile B or C bituminous
rank.
Navajo Field
Navajo Field is currently being strip mined with
an overburden of less than 250 feet and an average
of 120 feet. The coal is high-volatile B bituminous
coal and high-volatile C bituminous coal. Coal seams
average H to 10 feet thick.
Newcomb Field
Newcomb Field has reserves of strippable coal
with less than 250 feet of overburden. Minable
coal occurs in irregular thicknesses, 4 to 8 feet
and limited areal extent. The coal is subbituminous
A /-\irt D
A or B.
Bisti Area
Bisti area is the largest underdeveloped strippable
coal reserve and is about 35 miles long. This could
be because of the limited transportation to the
center of the San Juan Basin; only gravel and dirt
roads reach the area. The overburden is shale and
soft sandstone. Thus, strip mining would be inexpen-
sive. The overburden is less than 250 feet thick.
The coal is subbituminous A.
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Star Lake Area
Star Lake area is about 55 miles long. The
strippable coal is as much as 15.9 feet thick,
but includes many thin partings of bone coal and
shale. The overburden is less than 250 feet
thick. Further exploration should reveal more
coal than estimated.
Chaco Canyon and Chacra Mesa Area
Small drifts and pits operated by the Navajo
Indians are the only mines. There are strippable
reserves with 5 to 6 foot seams. There are
other areas that are thin and overlain by a
prohibitive thick overburden of Cliff House
Sandstone. Recent work on the Menefee coals
shows large reserves, but at depths below 500
feet.
La Ventana Field
La Ventana Field has small intermittent active
underground mines. There are large accounts of
reserves but due to 80° slopes and thick sand-
stone overburden in places, not all is strippable.
Minable seams are 6 to 8 feet thick.
South Mount Taylor and East Mount Taylor Fields
Small drifts have been mined for local use.
Thick volcanic sequence of Mount Taylor overlies
most minable coal and prevents strip mining
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except in small areas. Mlnable coal ranges from
3-5 to 7 feet thick and is high-volatile C
bituminous coal.
San Mateo Area
San Mateo area has strippable coal 3 to 6 feet
thick with some area 12 feet thick. The overburden
is less than 250 feet thick.
Standing Rock Area
No major reserves are evident from surface con-
ditions, but analysis has shown that some areas
are strippable.
Crownpoint Field
The coal is subbituminous A and subbituminous
B coal and mined by the Navajo Indians in small
drifts with seams 3-5 to 6 feet thick. Considerable
deep reserves may be present.
Gallup Field
There was large scale underground mining, but
most mining today is done by strip mining. The
remaining strippable coal has an overburden of
less than 250 feet and is high-volatile coal.
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Zunl Field
This field is covered by Cenozoic volcanic
rock and the out-cropping coal seams are thin.
Considerable reserves of deep coal and of coal
seams beneath thick sandstone are strippable.
Monero Field
In part of the field, on the backslopes of
cuesta blocks, considerable strippable coal may
be present, using geologic projection, but neither
outcrops nor drill data are available. Beds as
much as 7.3 feet thick have been mined, and the
underground reserves should be considerable.
However, dips of more than 5° and some faulting
may make mining difficult. The coals are of
high-volatile bituminous B or A rank.
Kottlowski and Shomaker describe fields in other parts of
New Mexico.1
Tierra Amarilla Field
Most of the nine coal seams are thin and are
overlain by excessive cover which includes massive
sandstone. The coal is subbituminous A and is
mined for local use only, with seams 9.6 feet thick.
The coal is high-volatile C bituminous rank.
Cerrillos Field
The field is a complex syncline in which the
coal-bearing rocks have been broken by many faults
and have been intruded by swarms of dikes and sills.
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Near thick Igneous sheets, the coals have been
metamorphosed to semianthracite and anthracite.
The coal-bearing strata are in the Mesaverde
Formation; the major beds, ranging up to 6 feet
in thickness, have yielded considerable tonnages
of anthracite and bituminous coal.
Raton Field
The Raton Field in northeastern New Mexico lies
on the western edge of the Great Plains in a
rugged, dissected plateau country Just east of
the Sangre de Cristo Mountains. Many west to
north-west-trending canyons reach into this
plateau and provide easy access to the coal seams,
which are almost horizontal drifts from the
canyons. Only in a few localities is the over-
burden thin enough to allow strip mining, but
considerable reserves can be strip mined. The
York Canyon seam, which is 6 to 13 feet thick, is
presently being mined. Most of coal seams are of
high-volatile A to B bituminous coking coal.
Mining has been essentially continuous in the
field since about 1870.
Una del Gato Field
The Una del Gato Field lies in southeastern
Sandoval county, in a dissected valley drained
by Tonque Arroyo between the Sandia (north of)
and Oritz Mountains. The coal seams are 3 to 5
feet thick, occur in the Mesaverde Group, are
of high-volatile C bituminous rank, and are cut
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by numerous faults. Several small underground
mines operated near Hagen in the 1900Ts but the
field's remoteness and the difficulties of
mining caused by the complex geologic structure
stifled growth.
Tljeras Field
The coal bearing rocks are in the Mesaverde Group,
and occur in a small down-dropped fault block, the
Tljeras Graben. The strata are folded into two
synclines and the intervening anticline, and dip
steeply. Several thin beds of bituminous rank coal
drop out, but only a few tons have been mined for
local use.
Carthage Field
There are two seams ranging from 4 to 7 feet
thick. Part of it is excellent coking coal of
high-volatile C bituminous rank. This small field
occupies about 10 square miles and is cut into a
mosaic of small fault blocks, making mining diffi-
cult and expensive. Since 1950 only a single small
underground mine has operated for local use only.
Jornada del Muerto
Windblown sand conceals much of the bedrock, the
area is remote, and there has been no mining.
The few outcrops are of coal similar to that mined
in the Carthage Field, but maximum thicknesses are
only 3 feet for coal outcrops. Drilling could find
considerable reserves, as the Cretaceous strata
extend for a length of at least 10 miles.
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gngle Area
Prospect pits have opened thin lenses of coal and
drill holes have penetrated several coal beds in
the Mesaverde Group, but the apparent maximum
thickness of coal seams is 2 feet. However, dril-
ling is sparse and the Mesaverde Group strata do
underlie 60 to 100 square miles near the railroad
station of Engle.
Sierra Blanca Field
The seams are difficult to mine because the coal-
bearing beds are broken by many faults and in-
truded by numerous igneous dikes and sills associated
with the Sierra Blanca igneous complex. Outcrops
of the coal-bearing strata form a broken semicircle
on the west, north, and east sides of Sierra
Blanca. Not much of the coal can be strip mined
because of dips greater than 5° and excessive
overburden. Most of the seams are of high-volatile
C bituminous rank, and several are as much as 7
feet in thickness. Mining ceased in 1910 owing
partly to the unusually large number of "rolls",
lenses of sandstone that replace parts of the
seams, which made mining expensive.
North Dakota
Coal mined in North Dakota has traditionally been surface
mined due to the close proximity of coal to the surface
and the relative ease with which overburden can be removed,
Bureau of Mines describes North Dakota coals which are
nearly 100$ lignite as follows.2
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Lignite beds lie principally in the Tongue
River Member of the Port Union Formation of
Tertiary age. They are essentially flatlying
with dips of generally less than 1°. The beds
range in thickness from a fraction of an inch
up to 25 feet, and there are often two or more
beds of minable thickness in a particular area.
North Dakota is broken into four districts in which the
greater part of the commercial tonnage has been produced.
Carlson describes commercially important deposits in these
districts.l
Noonan-Columbus District
The Noonan-Columbus district is located in western
Burke and eastern Divide counties, where the
Noonan bed has been mined. This bed ranges from
7 to 10 feet in thickness with current operations
limited to Burke county.
Velva District
The Velva district is located in eastern Ward
county, where the Coteau bed is mined. The
average thickness of this bed is twelve feet.
Beulah-Zap District
The Beulah-Zap bed is mined in the western Mercer
county district at mines near Beulah and Zap. The
bed originally extended over an area of approximately
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500 square miles, from which a considerable
area has been removed by erosion. The thickness
ranges from 10 to lH feet in the area where
commercial operations are located. Thicknesses
from about 18 to 22 feet have been reported to
the north of these operations.
Hagel District
The Hagel bed is being mined in the Oliver-Mercer
county district near Stanton in eastern Mercer
county and near Center in Oliver county. In these
areas the Hagel Bed ranges in thickness form about
8 to 22 feet of lignite with an intervening clay bed
which varies from a few inches to as much as 6 feet
thick.
In addition to these four districts the Lehigh
bed, which is about 10 feet thick, is mined in Stark
county for local use and to supply a briquetting plant
at Dickinson. In Bowman county the Scranton bed has
been mined on a small scale, but current develop-
ment to supply a power plant In South Dakota will
propel this area into a major producing area.
Lignite is also mined for local use in a few counties
of the field; the combined output of these small
mines represents about 1!? of the total production
of the state.
Several other beds of potential importance have
been identified by the United States and North
Dakota Geological surveys, but no commercial
320
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developments have been undertaken due to the
unfavorable location with reference to presently
available water, transportation, and markets.
The lignite beds are practically level and in
most cases are covered with an impervious clay
that has prevented weathering of the lignite even
where the overburden is relatively shallow. These
conditions favor strip mining methods, particularly
where initial operations are on a scale to warrant
installation of heavy stripping equipment. Prepar-
ation plants at commercial mines are of modern
design. Because of the uniformity of the beds and
freedom from partings and impurities, no cleaning
plants are required.
Oregon
The following description of Oregon coalfields is repro-
duced entirely from Mason and Erwin (1955).9
Much of the coal found in the state is poor in
quality, and inability to compete with petroleum
products and coal from other western states has
greatly hindered mining development. Very little
recent geologic work has been done in any of the
coal-bearing areas except the Coos Bay region.
Only the Coos Bay field is convenient to rail,
highway, and ocean transportation. The other fields
lie at some distance from highways and railroads.
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Many of the coal deposits in Oregon are in forested
or in partly inaccessible regions, and little is
known about the extent of the deposits. Only about
600 square miles are underlain by known coal-bearing
rocks.
The Coos Bay field is the only coal-bearing area
that has consistently produced coal of commercial
value. Although the other areas have produced
coal for local consumption, mining operations have
been limited because of the small quantity and poor
quality of the coal, as well as the long haul to
market.
However, most of the known coal-bearing beds in
areas outside the Coos Bay field contain many
partings of bone, carbonaceous shale, and clay,
and are probably of sub-commercial value.
In the northern part of the Coast Ranges of Oregon
the coal-bearing formations crop out along the flanks
of the Coast Ranges anticline and the dip of the
strata ranges from 15° to 30°. The coal-bearing
formations throughout the southern part of the
Coast Ranges are folded into generally northward-
trending anticlines and synclines in which the dip
of the strata ranges from 5° to 40°, and locally is
more than 40°.
The folds in the Coast Ranges are complicated by
numerous high-angle faults which generally have north-
west or northeast strikes. Displacements on these
faults are usually small, but some can be measured
in hundreds of feet.
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Coos Bay Field
The Coos Bay field is located in the western part
of Coos county, Oregon. It is elliptical, approxi-
mately 30 miles long and 11 miles wide, with an area
of about 250 square miles. The topography of the
field is characterized by a number of extensive
sloughs tributary to Coos Bay and by flat-topped
hills covered with brush and second-growth timber.
The Coos and Coquille Rivers with their many tri-
butaries drain the area.
The field is by far the most important in the state
from the standpoint of production and reserves,
and it is the only area in which coal has been pro-
duced.
The coal in the Coos Bay field is subbituminous B,
subbituminous C, or lignite.
Eden Ridge Field
Throughout the region the beds dip at comparatively
low angles. In the north the beds dip from 5° to
15° SW and in the west as much as 17° E.
The coal is high volatile bituminous C and occurs
in rocks of the type formation of middle Eocene age.
In a few localities the coal beds attain a maximum
thickness of 9 feet; hwoever, the maximum thick-
ness of coal generally is less because of the many
shale and bone partings.
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Rogue River Field
The coal is of a middle to early Eocene age and
occurs in sandstones and shales of the Umpqua
formation that have been covered by extensive
lava flows. It is of subbltuminous A or B
rank and contains a large number of partings
and bands of impurities.
Exploration has not been extensive enough to
determine the geologic structure of the area,
and the fact that the Eocene sedimentary rocks
interfinger with lava flows makes it difficult
to determine the extent of the coal beds. Diller
(1909) noted that at most places in the field the
beds dip gently northeastward and that the quality
and quantity of the coal increases to the northeast.
There has been prospecting for coal throughout
the area, and in many places the coal has been mined
for local use. In the northern part of the field,
on Evans Creek, beds as much as 8 feet thick have*
been found, but the coal contains a number of clay
and sandstone partings. The coal found in the
central part, although of better quality, is
generally less than 1 foot thick. The coal found
in the southern part is very thin and contains a
large percentage of sulfur.
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Eckley Area
The area is located near the Sixes River in a
heavily timbered mountainous area, about 45 miles
south of the Coos Bay field. The coal in the
area is high-volatile C bituminous and occurs in
rocks of the Arago group of Eocene age. The coal-
bearing strata consist of shale and soft sandstone
that have a thickness of approximately 50 feet
and are exposed in only a few places. Where ob-
served, the beds are folded and faulted. The
thickness of the coal beds differ greatly from
place to place and as a result of folding and
faulting the coal occurs locally in irregular
masses. The coal contains many layers of carbonaceous
shale. There has been no production of coal from
this area.
John Day Basin Area
Bituminous coal, subbituminous coal, and some
lignite occur in the Mascall formation of Miocene
age. Most of the coal is impure, however, and
yields low Btu values. The coal ranges in thick-
ness from a few inches to about 3 feet. The
rocks enclosing the coal beds are composed largely
of tuff with interbedded flows of andesite and
other igneous material. The rocks have been highly
faulted and folded, making it impossible to trace
the coal outcrops for any distance.
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Other Coal-Bearing Areas
Other small areas of coal-bearing rocks in Oregon
have been described. In northwestern Oregon, coal
has been found in Multnomah, Marion, Clackamas,
Lincoln, Columbia, Yamhill, Clatsop, and Tillamook
counties. The coal in these counties is subbituml-
nous and occurs in rocks of Ollgocene and late
Eocene age. The largest area known to contain coal
in this part of the state included about 20 square
miles on the upper Nehalem River in Columbia county
(Diller, 1895). The coal beds are from 1 to 10
feet thick, but the thicker beds consist mostly of
carbonaceous shale. Coal has been found in an
area of about 10 square miles in the west-central
part of Lincoln county, but the thickest bed
reported from this area contains only 3 feet of
impure coal. Coal also occurs in southern Clatsop
county in the lower Nehalem River area, but no bed
thicker than 22 inches has been reported. In
southwestern Oregon, near Comstock in the north-
central part of Douglas county, thin impure coal
beds occur in the Spencer Formation of late Eocene
age. Small outcrops of subbituminous coal are also
found in the Lookingglass and Camas Valley districts
and on Little River, all in Douglas county. A small*
amount of lignite occurs in the northeastern part of
Malheur county in the eastern part of the state.
Little is known about the coal deposits in any of
these areas because the exposures and prospecting
have not revealed coal that is promising enough to
encourage commercial development.
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South Dakota
South Dakota lignite production reached a peak of 71,000
tons in 19^1. However, production has declined to a few
thousand tons in recent years. Lignite has been used
locally for fuel, and production from some beds has been
treated for the recovery of uranium. Noble describes the
general character of South Dakota coalfields.10
In South Dakota's northwestern corner, about
7,000 to 8,000 square miles are underlain by
rocks that in places are potentially coal-
bearing. Erosion has removed a large fraction
of the beds that were correlative with the
productive lignite beds. A small amount of
South Dakota's coal is of low sulfur subbitumi-
nous grade, but it is not commercially important.
Outlook for exploitation looks bleak, at least for
the next few years. The state has had no signi-
ficant commercial production since 1968, nor
have the exciting developments in the neighboring
states been duplicated in South Dakota. Extremely
sparse population in the coal area and the long
distances to potential markets are deterrents to
development. Also a deterrent is the fact that
neighboring Wyoming, North Dakota and Montana have
vastly greater reserves. Moreover, water is scarce,
coal is relatively thin and lenticular, and there
is no railroad through the heart of the coal area.
Although Rapid City, South Dakota, is the site of a
pilot plant for research in gasification, it is not
likely that full-scale gasification plants will be
constructed in the state in the near future.
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Utah
Bureau of Mines describes the strippable coal found In
Utah as follows.2 Most coals in Utah, however, are deep
minable only.
Deposits near Alton in the Kanab Field in the
southwestern part of the state appear favorable
for large-scale strip mining. However, markets
must be established before the deposits can be
developed. Water supplies near these reserves
appear inadequate for the development of mine-
mouth electric generating facilities. The Kanab
coalfield contains the largest known reserves of
strip coal in the state. These occur in one of
two prominent coalbeds in the Cretaceous Tropic
Formation. The upper coalbed is about 400 feet
above the lower and is considered strippable
where overburden is 10 to 60 feet. Average
minable coal thickness of the upper seam is 11
feet.
Shepardson describes the Utah fields in the following
excerpts from the Keystone Coal Manual.1
Book Cliffs Coal Field
Dips are generally 3° to 7° and in some areas
up to 15°. The seams are generally H feet thick
and 3000 feet deep. It is the leading producer
In the state.
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Book Cliffs coal Is convenient to the mainline
of the Denver and Rio Grande Western Railroad and
could be moved to a site on the Green River
(perhaps near the town of Green River, Utah) by
rail or perhaps by slurry pipeline. It has been
stated that water was available to satisfy the
cooling needs of a thermal power plant with a
generating capacity in excess of 2600 Mwe. It
is possible that these two opportunities could
be joined.
Sego Area
Sego area occupies 390 square miles. The field
is dormant now because the principal market for
this coal was the steam locomotive. The bulk of
the reserves is in the Cretaceous Chesterfield
Formation. The best coal is in the western area.
Wasatch Plateau Field
There are eight mines in operation with more
being opened. There are over 20 beds with coal
more than 4 feet thick. Mining problems in
Wasatch Plateau field include thick overburden,
faulting, burned coal, water problems, and
others, all of which have been successfully over-
come by operators, but these problems have
forced the costs of extraction to about the
$4.40-per-ton level (1973). Present-day acti-
vity in this coalfield was prompted by the
recognition that a large supply of water would
be impounded in the southern end at Lake Powell.
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Emery Coalfield
The Emery Field occupies 210 square miles. Seams
are H feet thick. Very general estimated mining
costs range from $6 to $7 per ton for these
underground seams (1973).
The Emery field, some time ago, was proposed as
a potential power plant site. Any power plant
sited here today and using present-day technology,
would face high water-acquisition cost and quite
likely some air pollution problems. The field
may have eventual possibility as a gasification
site.
Henry Mountain Field
This field covers 450 square miles with seams
more than 4 feet thick at depths of 3,000 feet
or less. The Emery seam is today the most
clearly attractive and might eventually supply
power plants possibly sited on the Fremont or
Escalante rivers. The field contains some strip
reserves, an unusual condition in Utah. However,
the remoteness of the area and the uncertainty
of the water supply suggest that development
may be some time in the future.
Alton Field
This field is strippable with an overburden of
less than 80 feet and thickness of 12-20 feet.
The area is interesting since much strip over-
330
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burden can be removed without blasting, and
mining costs might consequently be below $2.50
per ton (1973).
Goose Creek Lignite Field
Goose Creek Lignite Field is far removed from
the necessary water and transportation facility.
Reserves are high in ash (ash contains occasional
interesting uranium values), and are minable by
underground methods. Goose Creek would not be
economic in the foreseeable future, and opera-
tions are not now conducted there.
Lost Creek Coal Field
This field covers 6,400 acres with beds that
are 4 feet thick. The area is not being mined
presently.
Sevier-San Pete Field
This field covers 30 square miles with beds
that are 4 feet thick. The area is not being
mined now.
Salina Canyon Field
The field covers some ltd square miles and is
estimated to contain about 85 million tons of
coal in beds of 4 feet or more. Cover is 3,000
feet. Operations are not now being conducted here
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Wales Field
Wales field is not in operation now. it covers
5.5 square miles. The bed is H feet thick or
more. Cover is approximately 3,000 feet.
Sterling Field
Sterling Field covers 2 square miles and is H
feet thick with cover approximately 3,000 feet
thick.
LaSal-San Juan Fields
Coal in this remote and arid region appears to
be of academic interest only. Throughout the
potential area of 17,000 square miles, explora-
tion to date has established no reserves in beds
over H feet in thickness.
Tabby Mountain Field
While water might be available to support a
consuming plant, the low Btu of the coal, coupled
with the steep dips (over 30°) of the beds fre-
quently found, indicate that this field will not
have much development in the near future.
Coalville Field
One mine, producing about 12,000 tpy, is opera-
ting at this time. The major seam is the Wasatch
which is about 8 to 10 feet thick. This field
332
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will probably continue bo serve small truck
markets. However, only passable roof and floor
conditions, steep dips in the beds, and the spon-
taneous combustion of the coal product suggest
that markets will be quite limited.
Henry's Fork Field
All prospecting in this area appears to have
occurred prior to World War I. While this field
might be as long as 100 miles, width is probably
no more than 1 mile. It is limited on its south
side by severe faulting, occurring in the north
flank of the Uinta Mountains. There appears to
have been little or no production. At most, four
mines may have operated in purely local markets.
Rail transport is over 20 miles away. There is
no present activity in the area and the field
appears now to be of academic interest only.
Kolob-Harmony Field
There is no mine in operation. The field covers
384 square miles. Coal is quite variable in its
characteristics throughout the field. A major
technological shift must occur before this field
becomes competitive.
Vernal Field
Beds are over 4 feet thick. There are moderate to
steep dips. The beds are rarely over 5 feet thick
and contain many splits. The Vernal field is
333
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situated in Uintah basin which is a well-watered
area. Utah Power & Light and others are seeking
water appropriation to support various plants. If
the characteristics of the coal and the structural
geology of the field can be economically overcome,
this field should see later development.
Washington
The single most important deposit of strippable coal is
northeast of Centralist in Lewis and Thurston counties.
The deposit in the Centralia-Chehalis area contains the
Big and Smith seams of the Skookomchuck Formation of late
Eocene age. Over 90% of the strippable reserve is in the
Big seam. Coalbed thicknesses range from 5 to 50 feet.
Other coal areas of lesser interest are as discussed by
Livingston.l
Whatcom County Area
This area covers 500 square miles. Some dips are as
high as 60°. Seams average between 7 and Hi feet
thick. Of special interest in Whatcom County, because
it contains anthracite coal, is the Glacier field.
For years operators have attempted to work this field
but to date all attempts have failed.
Skagit County Area
This coal area covers 700 square miles. The beds have
been mildly to severely deformed and dip up to 70°.
The analysis data is limited; the rank is bituminous.
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Issaquah-Grand Ridge King County Area
This area is broken down into 6 areas:
1. Newcastle-Grand Ridge Area. Dips are general-
ly 30° to 40° but increase to 75° in Grand
Ridge Area. The coal beds are in nonmarine
rocks of the Puget Group and are probably
near the top of the Eocene section. The
thickness of the beds ranges up to 17 feet.
2. Cedar Mountain Area. The coal is generally
subbituminous to high-volatile C bituminous.
Because of poor data, it has not been possible
to correlate the seams with any degree of
certainty from one side of the fault to the
other.
3. Renton Area. Folding in the area has been
moderate to intense with maximum dips reach-
ing 65°. The coal is subbituminous A or high-
volatile C bituminous. Seam thickness is 5 to
8 feet.
4. Tiger Mountain Area. The coal occurs in the
rocks of Puget Group. The rocks have been
folded and the beds strike northeast and dip
about 45°. The coal is subbituminous B rank.
The thickness is between 3 and 6 feet.
5. Niblock Area. Little is known about the
geology of this area. The coal seams occur
in the Puget Group but their stratigraphic
position is not definitely known. The beds
strike about north 1|5° west and dip up to
75° to the southwest. The coal is high-
volatile A bituminous rank. Some coal has
been mined.
335
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6. Taylor Area. The coal beds crop out around
the nose of a southeast-plunging syncline with
dips ranging from 40° to 80°. The coal is
high-volatile A bituminous and high-volatile B
bituminous. There are ten beds with seams
ranging from 3 to 5 feet.
Green River-King County Area
The coal-bearing rocks have been extensively folded
into a series of north-to-northeast and northwest-
tending anticlines and synclines. Some folds may have
displacements of over 1,000 feet. The rank ranges
from subbituminous B to high-volatile A bituminous;
however, most of it is high-volatile B bituminous.
Wllkeson Carbonado-Pierce County Area
The rocks have been tightly folded into a series of
north-northwest-plunging anticlines and synclines.
Dips are moderate to high ranging from 30° to vertical.
The seams range from 2 to 14 feet thick. The coal Is
ranked' from low-volatile B to high-volatile A
bituminous.
Fairfax-Ashford Area
The coal is in sedimentary rocks and the beds are
intruded by igneous rock. Stratigraphic relations
have not been determined yet. Dips in the area are
usually steep, 60° and higher being quite common. The
coal varies in rank from low-volatile B to high-volatile
A bituminous and has coking qualities. Only limited
336
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production has been reported from the Fairfax Area
and none from the Ashford Area. The seams are 3 to 1*1
feet thick.
Morton Area
Little is known about the geology of the coal seams.
The coal seams dip steeply to the west along the west
limb of a north trending anticlinal structure. The
rank is mostly high-volatile bituminous. There are no
reports of significant production.
Eastern Lewis County Area
The coal is in sedimentary rocks of Eocene age. The
coal has been subject to such intense deformation that
some of it is anthracite in rank; however, it is very
bony and has a high ash content. There has been no
production.
Kelso-Castle Rock Area
The coal rank is lignite to subbituminous B. No coal
has been mined since 1890. The coal-bearing rocks in
this area have been gently folded into broad open
northwest-trending anticlines and synclines. Dips of
the beds are low, rarely exceeding 25°• Faults are
present but of small displacement.
Roslyn-Kittltas County Area
The coal rank ranges from high-volatile A bituminous
to high-volatile B bituminous. The seam thickness
ranges from 2 to 15 feet.
337
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Taneum-Manastash Area
The rank is high-volatile A bituminous and no coal
has been produced.
Wyoming
General characteristics of Wyoming's strip coal deposits
are reproduced from the Bureau of Mines.2
Coal-bearing strata are of Upper Cretaceous and
Tertiary ages. The most significant strip-coal
deposits are of Tertiary age in the northeastern part
of the state; they include the 30- to 130-foot-thick
Roland coalbed and the 10- to 40-foot-thick Felix
coalbed. These two coalbeds crop out for more than
100 miles along the east flank of the Powder River
Basin and contain a major part of the state's
strippable reserves.
There are 10 major regions which underlie more than 40,000
square miles of the state of Wyoming. Most coal regions
are strippable. A short description of the regions and
their seams is listed below (Glass).1
Powder River Coal Basin
This basin covers over 12,000 square miles in north-
eastern Wyoming. Dips are usually less than 5° on
the eastern side, steeper on the western side. Most
338
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of the coal is subbitumlnous C rank. Important coal
seams in the Powder River Basin are as follows:
1. Badger Seam. The seam ranges between 17
and 20 feet in thickness. It is currently
strip mined in Converse County. It is
best developed in the Glenrock Field.
2. Canyon Seam. It is best developed in the
Spotted Horse Field in portions of Campbell
and Sheridan counties. Its thickness ranges
from 11 to 20 feet. There are no active
mines on this seam.
3. Carney Seam. This seam is well developed in
Sheridan Field. In thickness it averages
15 feet and ranges between 7 and 20 feet.
The Carney seam is not currently mined.
4. D Seam. This seam is important in the
southern part of the Gillette Field, and
averages. 8 to 16 feet in thickness. Maxi-
mum thickness is 65 feet. The D seam is
currently strip mined in Converse County.
5. E Seam. This seam underlies the D seam in
the southern portion of the Gillette Field.
It averages 5 feet in thickness. E seam is
not being mined.
6. F Seam. The seam is well developed in
portions of the Dry Cheyenne and Gillette
Fields in Converse County. Bed F has a
maximum thickness of 11.6 feet but averages
only 7.5 feet. It is not currently being
mined.
7. Felix Seam. The Felix seam is important
in Spotted Horse Field in Campbell County.
339
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It ranges between 5 and 21 feet in thick-
ness with an average of 12.5 feet. The seam
is not being mined.
8. Healy Seam. The Healy seam in the Buffalo
Field in Johnson County ranges between 5 and
25 feet at outcrop, but is as much as 220 feet
thick. It is not currently being mined.
9. Monarch Seam. This seam is the most impor-
tant seam in Sheridan Field. Thickness
ranges from 18 to 57 feet. The seam is strip
mined in Sheridan Field.
10. School Seam. The seam is important in
Glenrock Field of Converse County. The seam
averages 35 feet in thickness and ranges
from 22 to 38 feet. The seam is strip mined
in Converse County.
11. Smith Seam. This seam is well developed in
the Spotted Horse Field. It ranges between
5 and 13 feet in thickness. The seam is not
being mined.
12. Sussex Field (lower bed). This "lower bed"
in "Basin No. V of the Sussex Field averages
11.8 feet thick but reaches a maximum of 50
feet. There is currently no mining of this
seam.
13. Wyodak Seam. It is best developed in the
Powder River and Gillette fields. The seam
averages 71 feet thick but ranges between 55
and 106 feet thick. It commonly has an 8-
inch parting 38 feet above its base. The
seam splits into two separate seams to the
west with the lower branch ranging between
22 and 35 feet in thickness. The interval
3^0
-------
between the two benches goes up to 100 feet.
To the north the seam splits into 5 or more
beds varying from 5 to 31 feet in thickness
and separated by 4 to 33 feet of clay and
shale. The Wyodak seam is currently strip
mined in Campbell County.
1^. Roland-Smith Seam. See Wyodak seam.
Green River Region
The Green River Region covers about 15,^00 square miles
of southwestern Wyoming. It is divided into two major
structural basins by the Rock Springs anticline: the
Green River Basin to the west and the Great Divide
Basin to the east. Dips in this region are small
except around the Rock Springs uplift and the western
margin. Dips on the western side of the Rock Springs
Uplift go up to 20°, and on the eastern side 10°.
Along the western margin of the region, dips range
between 20° and 50° in some areas.
Coal ranges in rank from subbituminous C to high-
volatile C bituminous. The higher rank coals occur on
the eastern margins of the region as well as around
the Rock Springs Uplift. Important coal seams in the
region are as follows:
1. B and C Seams. These two unmined seams are
subbituminous A coals of the Wasatch Form-
ation and reach their maximum development in
the northern part of the Little Snake River
Field. The B seam ranges from 10 to 18 feet
in thickness and normally has a 1- to 2-foot
341
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parting in it. The C seam, which is 4o to 70
feet below the B seam, ranges in thickness
between 20 and 32 feet. It has a 1- to 1-1/2-
foot parting. In places these two seams
coalesce into a single seam of 30 to 40 feet
in thickness, which has a parting up to 4 feet
thick.
Battle No. 1 and No. 2 Seams. These two sub-
bituminous B coals outcrop in the southeastern
part of the Great Divide Basin Field. They
are seams of the Wasatch Formation. They
average between 6.4 and 8.6 feet in thickness.
Creston No. 2 and No. 3 seams. These seams
are in the Wasatch Formation in the Great
Divide Basin Field. They outcrop in the
southeastern part of the field where they
average about 18 feet in thickness. They are
subbituminous B in rank.
Hadsell No. 2 Seam. This is another Wasatch
seam outcropping in the southeastern part of
the Great Divide Basin Field. It is sub-
bituminous B in rank and averages 7.7 feet
thick.
Jim Bridger Seams. Two coal seams of the Fort
Union Formation are exceptionally well devel-
oped on the western edge of the Great Divide
Basin Field. These seams have been referred
to as the Jim Bridger deposits. Each seam
averages 15 feet thick, and where the two
seams coalesce into a single seam, it is 30
feet in thickness. The seams are probably
subbituminous in rank.
-------
6. Latham No. 3 and No. 4 Seams. The Latham
seams are best developed in the southeastern
part of the Great Divide Basin Field. They
occur in the Wasatch Formation and are sub-
bituminous B coals. Average thickness is 5.7
feet.
7. Rock Springs No. 7 Seam. This seam averages
4.5 feet in thickness, is high-volatile C
bituminous in rank, and occurs in the Rock
Springs Formation of the Mesa Verde Group in
the Rock Springs Field.
8. Rock Springs No. 11 Seam. The No. 11 seam is
high-volatile C bituminous coal, ranges from
44 to 54 inches in thickness, and averages
4 feet thick. It is an important seam in the
Rock Springs Field. This seam is in the Rock
Springs Formation.
9. Sourdough-Monument-Tierney Seams. This group
of coals is actually five seams that occur at
about the same horizon in the Wasatch Forma-
tion in the southeastern part of the Great
Divide Basin Field. Because at times these
seams coalesce with one another, separation
of the coals into individual beds is not
always possible. In places, each of these
subbituminous B coals exceeds 5 feet in thick-
ness .
Hanna Field Region
Coal-bearing rocks of the Hanna Field outcrop in a
750 square mile area of Carbon County in south-central
Wyoming. Most simply, the Hanna Field occupies a
3^3
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structural trough that is divided into two separate
basins by a northeast-southwest trending anticline.
The Hanna Basin lies to the northwest of the anticline
while the Carbon Basin lies to the southeast. The
Hanna Field is bounded on the north, west and south by
mountain ranges. Faulting is common in the field.
Coal seams occur in the Mesa Verde Group and Medicine
Bow formations of Upper Cretaceous age, the Ferris
Formation of Upper Cretaceous and Paleocene age, and
the Hanna Formation of Paleocene and Eocene age. The
rank of the coals in the Hanna Field ranges from sub-
bituminous C to high-volatile C bituminous. The
highest ranked coal, high-volatile C bituminous, occurs
in the Mesa Verde Group. Collectively, coals of this
group and the Medicine Bow formation range downward
in rank to subbituminous B. The Hanna Formation and
Ferris Formation coals are predominantly subbituminous
although the Hanna No. 2 seam of the Hanna Formation
has reportedly been ranked as high as high-volatile C
bituminous.
The important seams in the Hanna Field are as follows:
1. Bed No. 25. Bed No. 25 is a minable seam in
the lower third of the Ferris Formation and
is best developed on the west side of the
Hanna Basin. The seam averages 22 feet in
thickness and is of subbituminous rank. it
is currently strip mined in Carbon County.
2. Bed No. 50. This coal seam occurs near the
middle of the Ferris Formation and is sub-
bituminous coal. The seam is best developed
-------
in the Hanna Basin portion of the field. It
averages 15 feet in thickness and has been
strip mined in Carbon County.
Bed No. 50. This Ferris Formation coal is of
Paleocene age. It is subbituminous in rank
and is the only seam currently being deep
mined in the field. The seam is important in
the Hanna Basin and ranges from 6 feet to 8
feet in thickness. Its average thickness is
7 feet.
Bed No. 80. No. 80 is a Paleocene coal of the
Hanna Formation. The rank is subbituminous.
This seam is well developed in the Hanna Basin
where it ranges from 15.5 to 24 feet in thick-
ness. The No. 80 bed generally has a 1- to
1-1/2-foot parting 2 to 5 feet above its base.
It is strip mined in Carbon County.
Bed No. 82. This seam is an Eocene coal in
the Hanna Formation. It is subbituminous
coal and averages 9 feet thick. It is best
developed in the Hanna Basin and is strip
mined in Carbon County.
Brooks Seam. This seam is a subbituminous
Paleocene coal near the base of the Hanna
Formation. It ranges between 8 feet and 15
feet in thickness and is strip mined in Carbon
County.
Hanna No. 2 Seam. Although this seam is not
presently being mined, it has been extensively
deep mined and strip mined in the Hanna Basin.
This coal is normally of subbituminous A rank,
but in places it is ranked as high-volatile C
bituminous. These higher ranked occurrences
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are where the seam is not weathered. The
Hanna No. 2 Seam ranges in thickness from 30
to 35 feet. The seam is usually divided into
three benches by partings.
Hams Pork Region
This region is the westernmost of the coal-bearing
areas. Because it is highly folded and thrust faulted
the coal-bearing rocks outcrop in long narrow belts.
The coal-bearing rocks of this region are the Bear
River, Frontier and Adaville formations of Upper
Cretaceous age and the Evanston Formation of Paleocene
age. Coals in this region range between high-volatile
A bituminous and subbituminous B. Coals up to 20 feet
thick occur in the Frontier Formation and are the high-
er ranking seams. The Adaville Formation coals are
subbituminous B rank and attain thicknesses over 100
feet.
Adaville Seams
These seams are the most important coals in the region
and are best developed in the Kemmerer Field. At least
seventeen seams in this formation exceed 6 feet in
thickness. The Adaville No. 1 seam is the thickest and
attains thicknesses in excess of 100 feet. Some pro-
duction of the No. 1 seam is used to make chemical coke
for the phosphorous industry as well as experimental
metallurgical grade coke. All the seams have partings
which range from 1 inch to 15 feet in thickness. These
coals are all subbituminous B in rank. All the current
mining on these seams is by surface methods.
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Bighorn Basin
The Bighorn Basin is a broad structural basin bounded
on the east, south and west by mountain ranges. Coal-
bearing rocks underlie about 4,400 square miles of the
basin. They are exposed in the folded rocks around
the margin.
In these folded edges of the Bighorn Basin, dips as
steep as 50° are common.
Coals in the more central portion of the basin are
under deep cover and little is known about them. Most
of the coals are lenticular and of limited extent,
especially along the eastern side. Thicker and more
extensive coal seams occur on the southern and western
sides.
Coal in the northernmost part of the Bighorn Basin is
high volatile C bituminous in rank while the remaining
part of the basin contains subbituminous A and B coals.
Gebo Field Seams (Uncorrelated)
One uncorrelated coal seam is currently mined in the
Gebo Field. The seam ranges between 7 and 9 feet in
thickness, but averages only 7 feet. The seam is mined
underground by conventional methods.
Grass Creek Field Seam (Uncorrelated)
One uncorrelated seam in the Grass Creek Field is
currently being deep mined by conventional methods.
-------
The coal seam ranges from 20 to 50 feet in thickness
and has been strip mined in the past.
Wind River Coal Basin
The Wind River Basin is a large asymmetrical syncline
in central Wyoming. Dips are steeper on the northern
side than on the southern. Many minor folds and a
number of faults complicate the basin. Coal bearing
rocks are the Cody Shale, Mesa Verde and Meeteetsee
formations of Upper Cretaceous age and the Fort Union
of Paleocene age. Coal-bearing rocks outcrop around
the margins of the basin. Coals in the central part
of the basin are under considerable cover. Coals are
believed to be subbituminous.
Jackson Hole Coal Region
The Jackson Hole Field in northwestern Wyoming is
underlain by minable seams over an area of 700 square
miles. Minable coals occur in Upper Cretaceous,
Paleocene and Eocene age rocks. The coal is probably
subbituminous rank.
Black Hills Coal Region
The Black Hills Region is in the extreme northeastern
part of the state. Coal outcrops in a narrow, discon-
tinuous belt through the region. Minable coal is
confirmed to the base of the Dakota Sandstone of Lower
Cretaceous age. The field as a whole is usually
considered to be "mined out." The coal in this field
is high-volatile C bituminous and is a moderately good
coking coal.
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Rock Creek Coal Region
The Rock Creek Field is a small field southeast of
the Hanna Field. Coal-bearing rocks occur in the
Mesa Verde Group of Upper Cretaceous age and the
Hanna Formation of Paleocene and Eocene age. The
thickest and best exposed coal seams are in the
northwestern part of the field. Coal in the field
is subbituminous B rank.
Goshen Hole Coal Region
The Goshen Hole Field is in the southeastern part
of the state. Coals in the field occur in the
Lance Formation of Upper Cretaceous age. No coal
more than 2.5 feet thick is known to exist in this
field. The coal is probably of subbituminous rank.
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APPENDIX C
WESTERN COAL PRODUCTION BY MINE FOR 1972 AND 1973
INCLUDING COALSEAM/ACTIVE MINE
NOMENCLATURE ORGANIZATION
351
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Production data for 1972 and 1973 are compiled for the 10
western states included in this report. Oregon and South
Dakota showed zero production for 1972 and 1973. The data
for large mines (over 1 million TPY) in 1973 are presented
in Table C-l. Table C-2 is a compilation of 1972 production
data from the 1973 Keystone Coal Industry Manual. Table
C-3 relates coalfields to active mines as of 1971 and seams
worked in those mines.
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Table C-l. WESTERN COAL MINES
PRODUCING OVER ONE MILLION TONS PER YEAR IN 1973.23
(organized by overall U.S. size ranking)
uo
VJ1
VJ1
Size
Rankinga
1
6
12
13
18
20
26
45
53
67
116
118
131
Company
Utah International
Western Energy Co.
Peabody Coal Co.
Washington Irrigation Dist .
Pacific Power & Light Co.
Arch Minerals Corp.
Kemmerer Coal Co.
Peabody Coal Co.
Knife River Coal Mining Co.
Rosebud Coal Sales Co.
North American Coal Corp.
Pittsburgh & Midway Coal
Mining Co.
Kaiser Steel Co.
TOTAL
TOTAL WEST
% Production of Large Mines
Name of Mine
Navajo (S)
Colstrip (S)
Black Mesa (S)
Centralia (S)
Dave Johnston (S)
Semihole No. 1 (S)
Sorensen (S)
Big Sky (S)
Beulah(S)
Rosebud HA (S)
Indian Head (S)
Edna (S)
Sunnyside No. 1 (D)
State
New Mexico
Montana
Arizona
Washington
Wyoming
Wyoming
Wyoming
Montana
N. Dakota
Wyoming
N. Dakota
Colorado
Utah
Production
^ — P^^.^^^^^^^"^™™
7,389,321
4,253,681
3,2146,500
3,229,176
2,897,383
2,865,100
2,546,435
1,971,643
1,726,000
1,509,736
1,090,144
1,076,120
1,008,000
34,809,239
•58.000,000
60.0
— "-
aThere were 4,879 coal mines operating in the U.S. in 1972.
3S = strip, D = deep
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Table C-2. PRODUCTION DATA BY MINE FOR 19721
(thousand short tons)
UJ
ui
Corapany and City
Peabody Coal Co.
Bear Coal. Co . ,
Somerset
C.F.M. Steel Corp. ,
Weston
Clayton Coal
Erie
Colowoy Coal,
Craig
Corley Co. ,
Florence
Corley Co. ,
Florence
Energy Fuels Corp . ,
Steamboat Springs
Energy Fuels Corp.,
Steamboat Springs
Mine
Black Mesa #1
Bear
Allen
Lincoln
Red Wing
Corley Strip
Corley S & A
Energy Strip #1
Energy Strip #2
County
Arizo
NavaJ o
Color
Gunnison
Las
Animas
Weld
Moffat
Fremont
Fremont
Routt
Routt
Field
na
Black Mesa
Total Arizona
ado
Somerset
Trinidad
Boulder-Weld
Dan forth
Hills
Canon City \
Canon City *
Yampa \
Yampa '
Subtotal
Colorado
Type of Mine
Strip
2,953.6
2,953-6
0
0
0
0
NAa
121.916
NAa
769.277
891-223
Deep
0
0
1*3-331
616.327
327.028
135.992
0
0
0
0
0
1,222.678
Total
2,953-6
2,953-6
113-331
616.327
327.028
135-992
' " 121.916
769-277
2,113-901
aBA refers to individual mine tonnages not available
-------
Table C-2 (continued). PRODUCTION DATA BY MINE FOR 1972l
(thousand short tons)
Ul
Imperial Coal,
Erie
Mid-Continent C&C,
Carbondale
Mid-Continent C&C,
Carbondale
Mid-Continent C&C,
Carbondale
Mid-Continent C&C,
Carbondale
Mid-Continent C&C,
Carbondale
Peabody Coal Co. ,
Nuola
Pittsburgh & Midway
Coal Mining Co. ,
Oak Creek
Silengo Coal,
Craig
U.S. Steel Cor . ,
Somerset
Western Slope
Carbon Inc . ,
Somerset
Eagle
Bear Creek
Coal Basin
Dutch Creek #1
Dutch Creek #2
L. S. Wood
Nucla
Edna Strip
Wise Hill #5
Somerset
Hawks Nest #3
Colorado
Weld
Pitkin
Pitkin
Pitkin
Pitkin
Pitkin
Montrose
Routt
Mo f fat
Gunnison
Gunnison
Field
(cont . )
Boulder-Weld
Carbondale
Carbondale
Carbondale
Carbondale
Carbondale
Nucla-
Naturita
Yampa
Yampa
Somerset
Somerset
Typ
Strip
0
0
0
0
0
0
667.997
871.818
0
0
0
Total Colorado 2,131-068
= 01 line
Deeo
218.212
a.
NA
a
NA
652.352
(Total MC C8
... a
NA
..a
NA
0
0
171.205
371.0
261.319
2,907.796
Total
218.242
...a
NA
„ .a
NA
652.352
C)
...a
NA
...a
NA
6S7.997
874.818
171.205
371.0
261.319
5,311.364
aNA refers to individual mine tonnages not available.
-------
Table C-2 (continued). PRODUCTION DATA BY MINE FOR 19721
(thousand short tons)
t_0
VJl
oo
Company and City
Decker Coal Co.
Knife River Coal
Mining Co.
Peabody Coal Co.
Western Energy Co.
Kaiser Steel Corp.
Pittsburgh & Midway
Coal Mining Co.
Utah International,
Inc.
Baukol Hoonan Inc .
Baukol Moonan Inc.
Mine
Decker No. 1
Savage
Big Sky
Colstrip
York Canyon
McKlnley
Nava J o
Baukol Noonan
Baukol Noonan 12
County
Monta
Big Horn
Riehland
Rosebud
Rosebud
New Me
Colfax
McKinley
San Jose
North I
Divide
Divide
Field
na
Decker
Breezy Plat
Colatrip
Colstrip
Total Montana
•xico
Ration
Gallup
Fruitland
Total
New Mexico
Dakota
Hoonan .
Noonan *
Subtotal
North Dakota
Type of Mine
Strip
800.0
320.975
1,601.181
5,500.7
8,222.856
0
397.02
6,898.262
7,295-282
NAa
2,086.76
NAa
2,086.76
Deep
0
S
duct
0
0
0
0
902.029
0
0
902.029
0
0
0
Total
800.0
Note:
tarted pro-
ion 8/22/72
320.975
1,601.181
5,500.7
8,222.856
902.029
397.02
6,898.262
8,197-311
2,086.76
2,086.76
HA refers to individual mine tonnages not available
-------
Table C-2 (continued). PRODUCTION DATA BY MINE FOR 19721
(thousand short tons)
CO
VJ1
Consolidation
Coal Co.
Consolidation
Coal Co.
Huskey Industries
Knife River Coal
Mining Co.
Knife River Coal
Mining Co.
North American
Coal Corp.
Lignite Divn.
— _
__
Mine
Velva
Glenn arold
No. 2
Beulah
Gascoyne
Indian Head
County
North Dako
McHenry
Mercer
Stack
Mercer
Bowman
Mercer
Ore
—
South
—
Field
ta (cont. )
Velva
Stanton
Dickinson
Beulah
Gascoyne
Beulah
Total
North Dakota
gon
—
Total Oregon
Dakota
—
Total
South Dakota
Type c
Strip
1469.608
1,1417.626
155-912
1,530.0
165.957
1,037-236
6,863-099
0
0
0
0
f Mine
Deep
0
0
0
0
0
0
0
0
0
0
0
Total
U69.608
1,417.626
155.912
1,530.0
165-957
1,037.236
6,863.099
0
0
0
0
-------
Table C-2 (continued). PRODUCTION DATA BY MINE FOR 19721
(thousand short tons)
(JO
o\
o
Company and City
American Coal
Browning Coal Co.
Carbon Fuel Co.
Kaiser Steel Corp.
Kaiser Steel Corp.
Kaiser Steel Corp.
Morth American
Coal Corp.
Peabody Coal Co.
Plateau Mining Co.
Premium Coal Co.
Southern Utah
Fuel Co.
Swlsher Coal Co.
United States Fuel
U.S. Steel Corp.
Western District
Coal Operations
Mine
Desert
Browning
Carbon Fuel
Sunnyslde #1
Sunny side 12
Sunny side #3
Castle Gate
Deer Creek
Plateau
Soldier Canyon
Mine No. 1
Swlsher
King Mine
Geneva
County
Ut,
Emery
Emery
Carbon
Carbon
Carbon
Carbon
Carbon
Emery
Carbon
Carbon
Sevier
Carbon
Carbon &
Emery
Emery
Field
ah
Wasatch Plateau
Wasatch Plateau
Book Cliffs
Book Cliffs
Book Cliffs
Book Cliffs
Book Cliffs
Wasatch
Wasatch
Book Cliffs
Sallna Canyon
Wasatch
Wasatch
Book Cliffs
Total Utah
Ty
Strip
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
>e of Mine
Deep
124. 91| it
124.0
322.225
960.961
85.360
118.105
231-998
303.544
310.0
107-418
184.023
260.0
558.576
716.0
"1,755.154
Total
424.944
124.0
322.225
960.961
85.360
148.105
231.998
303.544
310.0
107.418
184.023
260.0
558.576
716.0
4,755.154
-------
Table C-2 (continued). PRODUCTION DATA BY MINE FOR 19721
v (thousand short tons)
(JO
ON
H
Company and City
Palmer Coking
Coal Co.
Washington
Irrigation &
Development Co.
Amax Coal Co.
Big Horn Coal
Arch Mineral Corp.
Arch Mineral Corp.
Energy Development
Co.
Gunn-Quealy
Gunn Quealy
Kemmerer Coal Co.
Kemmerer Coal Co.
Pacific Power &
Light Co.
Mine
Rogers
Centralia Coal
Bell Ayr
Big Horn
Seminoe #1
Seminoe #2
Rimrock
Strip Mine
Rainbow #7
Rainbow #8
Elkol
Sorensen
Dave Johnston
County
Washin
King
Lewis-
Thurston
Wyom:
Campbell
Sheridan
Carbon
Carbon
Carbon
Lincoln
Sweet-
water
Lincoln
Lincoln
Converse
Field
gton
Green River
Centralia
Total
Washington
mg
Gilette
Sheridan
Harm a
Hanna
Hanna
Rock Springs
Rock Springs
Hams Pork
Hams Pork
Glenrock
Subtotal
Wyoming
Type
Strip
0
2,596. 721
2,596.721
32.957
955-0
2,060.506
120.219
850.0
0
0
259-323
1,813-596
2,618.137
8,739-768
of Mine
Deep
28.836
0
28.836
0
0
0
0
0
95.859
1.710
0
0
0
100.569
Total
28.836
2,596.721
2,625.56
32.957
955.0
2,060.506
120.219
850.0
95.859
1.710
259-323
1,813-596
2,618.137
8,810.337
• -
-------
Table C-2 (continued). PRODUCTION DATA BY MINE FOR 19721
(thousand short tons)
U)
o\
ro
Company and City
Resources Explor-
ation Mining
Rosebud Coal
Sales Co.
Wyodak Resources
Development Corp.
Rocky Kt. Assoc.
Coal Corp.
Mine
Rlmrock 142
Pit
Rosebud
Wyodak
County
Wyoming (
Carbon
Carbon
Campbell
Field
oont. )
Hanna
Hanna
Little Powder
River
Total
Wyoming
Total
Western
States
TV
Strip
525.130
1,355.0
622.620
288.656
11,531.171
1)1,896.803
se of Mine
Deep
0
0
0
0
100.569
8,69t.38t
Total
525.130
1,355.0
632.620
288.656
11,631.713
50,591-187
-------
Table C-3. COALFIELD IDENTIFICATION
oo
o\
OJ
State/Begion
Arizona
Black Mesa
Colorado
San Juan
San Juan
San Juan
Ulnta
Olnta
Ulnta
Field
Black Mesa
Cortez Dakota
Durango
Nucla-Naturlta
Book Cliffs
Grand Mesa
Tongue Mesa
Counties
Navajo
Apache
Coconino
Montezuma
Archuleta
La Plata
Mont rose
Garfleld
Delta
Delta
District
18
17
17
17
17
17
17
Seams8
Wepo *1
Wepo 12
Wepo 13
Wepo *1
Wepo 15
Wepo 16
Wepo 17
Wepo 18
unnamed
Hogback
Hesperus
fl
12
n
Anchor
Cameo
Carbonera
Palisade
A
B
C
D
P
Cimarron
Active Mine
Black Mesa 11
Black Mesa *2
—
—
Nucla Mine
—
—
—
Type"
S
S
~~
—
S
— —
—
Company
Peabody Coal Co.
n
"
"
Peabody Coal Co.
~~
— ~
aNumbers in parentheses refer to known seams actively mined In corresponding mines.
bS » strip mine; D « deep mine; C« captive mine
-------
Table C-3 (continued). COALFIELD IDENTIFICATION
uo
CTv
State/ReKlon 1 Field
Colorado Coont.)
Ulnta
Ulnta
Ulnta
Somerset
Crested Butte
Carbondale
Counties
Qunnison
Delta
Ounnlson
Oarfleld
District
17*
17
17
Seams a
(1) Somerset E
(3) C
Oliver D
(2) Hawk's Hest E
Bowie Shale Coals
Paonla Shale Coals
11
Kubler 12
14
IS
Black Diamond
A
B
C
D
Allen
Anderson
Sunshine
Coalesced A
Coalesced B
Placlta
(1) Coal Basin B
(2) Cameo
Active Mine
Bear Mine
(3)(1) Somerset
Mine
(2) Hawk's Nest
Bo. 3
—
Dutch Creek Mine
Typeb
D
D
0
D
(1)(2) L.S. Wood Klne D
Bear Creek Mine
D
Bear Coal Co.
U.S. Steel Corp.
Western Slope
Carbon
__
Mid-Continent
Coal and Coke
n
n
fNumbers in parentheses refer to known seams actively mined in corresponding nines.
S * atrlD mine: D « deeo mine: C » cantive.mine
-------
Table C-3 (continued). COALFIELD IDENTIFICATION
u>
Colorado (cont.)
Ulnta
Ulnta
Ulnta
Green River
•
Grand Hogback
Danforth Hills
Lower White
River
Yampa
Counties
Qarfleld
Rio Blanco
Mo I fat
Rio Blanco
Routt
District
17
17
17
17
Seams
Black Diamond
A
B
C
D
E
F
Allen
Anderson
Wheeler
Keystone 11
Keystone 12
Keystone *3
Keystone fl
Black Diamond
various
Fairfleld various
Lion Canyon various
(1) Collom
Brooks, Curtis 11
Pinnacle A
Bear River, Sun Mine B
Webber, Butcher Knife
—
(1) Red Wing Mine
T b
--
D
Colowyo-Coal Co.
aNumbers In parentheses refer to known seams actively mined in corresponding mines
bS " strip mine; D • deep mine; C - captive mine
-------
Table C-3 (continued). COALFIELD IDENTIFICATION
State/ReKion
Colorado (cont.)
Field
Green River (cont. )
-
District •'
Seams™
Rice Mine C
D
E
a
Wolf Creek H
(1) Wadge I
(2) Lennox 3
K
Crawford,
Sleepy Cat L
Corey M
N
0
P
Dry Creek Q
R
S
Lorella
Kimberly
Campbell
* Seymour
Wasatch Seams
Active Mine I
(1) Seneca Mine
(1) Energy Mine
(1)(2) Edna Mine
Wise Hill *5 Mine
Type" 1
S
3
S
D
Company
Peabody Coal Co.
Energy Fuels
Corp.
Pittsburgh t
Midway Coal
Sllengo Coal Co.
•
ers in parentheses refer to known seams actively mined In corresponding mines.
strip nine; D - deep nine; C » captive mine
-------
Table C-3 (continued). COALFIELD IDENTIFICATION
u>
cr\
State/Region
Colorado (oont.)
Raton Basin
Raton Basin
171 01 r\
F leiQ
Walsenberg
Trinidad
Counties
Huerfano
Las Animas
District
17
17
Seams8
Cameron
Lennox
Walsen
Pryor
Lower Robinson
Loner Rugby
Upper Rugby Primrose
Mutual
Benfind
Rainbow
Cameron
Empire
Walsen
Hustings A, B
Lower and Upper
Bunker Hill
Pryor
Rapson
Active Mine
—
(1) Allen Mine
Ludlow, lower I upper
(1) Ciruella (Allen)
Thomas
Gem, Robinson, Peerless
Piedmont
Morley, Lower Stark-
ville, Engleville
Upper Starkvllle, Upper
Morley 1
Typeb
—
O.D
Company
—
CF and I Steel
Corp.
"Numbers In parentheses refer to known seam, actively mined In corresponding mines.
bS - strip nine; D - deep mine; C - captive mine
-------
Table C-3 (continued). COALFIELD IDENTIFICATION
CO
o\
CO
State/Region
Colorado (oont.)
Field
Raton Basin (cont.)
Canon City
South Park
South Park
Canon City
South Park
North Park
Counties
Fremont
Park
Jackson
-
District
17
17
17
Seams3
Cokedale
Lower Soprls
Bear Canyon 16
Cass
Lower Rugby
Upper Rugby
Delagua
Bon Carbo
Frederick
Prlmera
Rockvale
Canon City
Magnet
Radiant , Jack-0-
Lantern
Royal Gorge, Basslck
Chandler, Llttel
Brookslde
(1) Black Diamond
lower
middle
upper
Sudduth
Lower Wlnscom
Upper Wlnscom
Coalmont unnamed 11
Active Mine
(1) Corley Strip
'
Type"
S
The Corley Co.
"Numbers In parentheses refer to known seams actively ml;
S • strip mine; D - deep mine; C » captive mine
ned In corresponding mines.
-------
Table C-3 (continued). COALFIELD IDENTIFICATION
U)
ON
VD
State/ReKion 1
Colorado (eont.)
Field
South Park (cont.)
South Park
Denver Basin
Denver Basin
Montana
Fort Union
Port Union
—
Middle Park
Colorado Spring
Boulder Weld
Decker
Hanging Woman
Creek
, • — '
Counties
Grand
i El Paso
Elbert
Douglas
Weld
Jefferson
Boulder
Denver
Adams
Arapahao
Big Horn
Big Horn
Rosebud
District
17
16
16
22
22
Powder Hiver
Seamsa . —
Coalmont unnamed 12
Coalmont unnamed *3
Coalmont unnamed IU
Reach
Mitchell
Monahan
Laramie A
Laramie, Buick
Matheson
Dawson, Raman Pondis
Scranton
11
12
Main Seam *3
fH
Middle S^am *5
Upper Seam »6
n
(1) Laramie *3
Anderson
(1) Deltz unnamed
Anderson
Deitz
—
norf in corresponding mJ
Active Mine
—
(1) Lincoln Mine
(1) Imperial Mine
(1) Eagle Mine
(1) Decker *1 Mine
~~
Twn»b
—
D
D
D
S
'otnoanv
—
Clayton Coal Co.
Imperial Coal Co.
Imperial Coal Co.
Decker Coal Co.
nes.
"S " strip mine; D - deep mine; C - captive mine
-------
Table C-3 (continued). COALFIELD IDENTIFICATION
U)
-3
O
State/Region
Montana (eont.)
Fort Union
Port Union
Fort Union
Fort Union
Fort Union
Fort Union
Port Union
Port Union
Fort Union
Fort Union
Fort Union
Port Union
Fort Union
Port Union
Port Union
Port Union
Field
Hoorhead
Poker Jim
Lookout
Roland
Squirrel Creek
Upper Rosebud
Blrney
Canyon Creek
Poker Jim O'Dell
Otter Creek
Ashland
Cook. Creek
Beaver Creek
Llscom Creek
Miller Green-
leaf Creek
Sweeney-Snyder
Creek
Colstrlp
Counties
Powder River
Powder River
Rosebud
Big Horn
Big Horn
Big Horn
Rosebud
Rosebud
Rosebud
Powder River
Powder River
Powder River
Powder River
Custer
Rosebud
Rosebud
Rosebud
District
22
22
22
22
22
22
22
22
22
22
22
22
22
22
22
22
Seams8
Anderson
Canyon
Deltz
Anderson
Deltz
Roland
Roland
Smith
Anderson
Canyon
Wall
Brewster-Arnold
Wall
Knoblock
Knoblock
Knoblock
Sawyer
Knoblock
Knoblock
Knoblock
Rosebud
Terret
(1) Rosebud
Active Mine
__
__
—
*
(1) Big Sky Mine
CD Colstrlp Mine
Type**
__
~
S
S
Company
—
Peabody Coal Co.
Western Energy
•"Numbers ln parentheses refer to known seams actively nin.rt <
b
-------
Table C-3 (continued). COALFIELD IDENTIFICATION
State/Region
Montana (eont.)
Fort Union
Fort Union
Fort Onion
Fort Union
Fort Union
Fort Union
Fort Union
Fort Union
Fort Union
Fort Union
Fort Union
Fort Union
Fort Union
Fort Union
Fort Union
Fort Union
Fort Union
Fort Union
Field
Sarpy Creek
Fire Creelc
Upper Cache
Creek
Lower Cache
Creek
Sonnette
Pumpkin Creek
Broadus
Sand Creek
Foster Creek
Pine Hills
Lame Jones
East Moorhead
Knowlton
Redwater River
Ueldon-Tlmber
Creek
Breezy Flat
Lamesteer
Wlbaux
Counties
Treasure
Big Horn
District
22
22
Powder River 22
Powder River 22
Powder River 22
Powder River 22
Powder River 22
Powder River 22
Custer
22
Powder River
Custer
Custer
Fallen
22
22
22
Powder River 22
Custer
HcCone
McCone
Richland
Vibaux
Wlbaux
22
22
22
22
22
22
Seams
Rosebud
He Kay
Pawnee
Pawnee
Broadus
Pawnee
Cook
Sawyer
Ferry
Sawyer
Broadus
Knob lock
Knoblock
Domlny
Domlny
Cache
Domlny
3
S
(2) Pust
Harmon
C
Active Mine
~-
—
—
—
—
—
—
—
—
—
~~
— —
~~
~~~
(2) Savage Mine
~
Type"
~~
. _ —
~~
~~
~—
~~
"
S
—
—
Company
""""
~~
7*
"
"
"~~
""
Knife River Coal
Mining Cc.
•—
—
"Numbers In parentheses refer to known seams actively mined In corresponding mines.
bS - strip mine; D - deep mine; C » captive mine
-------
Table .0-3 (continued). COALFIELD IDENTIFICATION
u>
-j
ro
State/Region
Montana (cont.)
Fort Union
Port Union
Fort Onion
Port Onion
Fort Onion
Fort Union
Fort Union
Fort Union
Fort Union
Fort Union
Fort Union
Fort Union
Fort Union
Fort Union
Fort Union
Fort Onion
Port Union
Port Union
Port Union
Bull Mountain
Bull Mountain
Bull Mountain
Field
Four Buttes
Hodges
Griffith Creek
Smith Dry Creek
O'Brlen-Alkalle
Creek
Burns Creek
N.F. Thirteen
Mile Creek
Fox Lake
Carroll
Port Kipp
Lanarck
Medicine Lake
Reserve
Coal Ridge
Cheyenne Meadows
Charter
Little Wolfe
Jeans Fork
Wolf Mountain
Bull Mountain
Carpenter Creek
Charter
Counties
Ulbaux
Dawson
Davrson
Rlchland
Wibaux
Rlchland
Daws on
Dawson
Richland
Rlchland
Daws on
Hoosevelt
Roosevelt
Sheridan
Sheridan
Sheridan
Rosebud
Mussellshelj
Big Horn
Big Horn
Big Horn
District
22
22
22
22
22
22
22
22
22
22
22
22
22
22
22
22
22
22
22
Mussellshell 22
Yellowstone
Mussellshell 22
Kussellshell 22
Seamsa
C
~
—
Q
—
Fust
Fust
Lane
Carroll
Ft. Kipp
Ft. Peck
Lanarck
—
—
Coal Ridge
Knoblock
Mammoth
Rosebud McKay
McKay
—
Roundup
Carpenter
Mammoth
Active Mine
—
—
—
~
—
—
—
—
—
—
—
—
—
—
--'
—
~
—
—
—
—
Type"
—
—
~
—
—
—
~
—
—
—
—
~
—
—
—
—
—
—
—
Company
—
--
—
—
—
—
—
—
—
—
—
—
—
—
—
—
—
aNumbera In parentheses refer to known seams actively mined in corresponding nines.
bS • strip nine; D • deep mine; C - captive mine
-------
Table C-3 (continued). COALFIELD IDENTIFICATION
-J
OJ
State/ReBlon
Montana (cont.)
Red Lodge
Red Lodge
Red Lodge
Red Lodge
Great Palls
Lewiston
North Central
Black foot
Valier
Electric Flel
Field
Red Lodge
Bridger
Sllvertip
Stillwater
Great Falls
Lewiston
North Central
Blackfoot
Valier
Electric
Counties
Carbon
Still
Carbon
Carbon
Stillwater
Cascade
Judith
Fergus
Liberty
Hill
Blaine
Choteau
Fergus
Glacier
Pondera
Tent on
District
22
22
22
22
22
22
22
22
Lewis it Clark
P__i, 1 22
arK 1
Seams8
unnamed 11
unnamed 12
unnamed 13
unnamed ib
unnamed #5
unnamed 16
unnamed #7
unnamed 18
unnamed 11
unnamed #1
unnamed 12
—
•~~
— ~
Judith River
St. Mary River
Active Mine
—
"
—
~~
~~~
Typeb
~~
Company
~
in parentheses refer to known seams actively mined in corresponding mines.
strip mine; D - deep mine; C <• captive mine
-------
Table C-3 (continued). COALFIELD IDENTIFICATION
uo
State/Region
Wont ana (cont.)
Livingston -
Trail Creek
Lombard
Flathead
Western
Tertiary
New Mexico
San Juan
San Juan
San Juan
San Juan
San Juan
San Juan
San Juan
Field
Livingston -
Trail Creek
Lombard
Flathead
Unnamed Various
Fruit land
Navajo
Blstl
Star Lake
Gallup
Barker Creek
Hogback
Counties
Qallatln -
Park
Gallatin
Broadwater
Flathead
Granite
San Juan
San Juan
San Juan
San Juan
McKinley
McKinley
San Juan
San Juan
District
'22
22
22
22
18
18
18
18
18
18
18
Seamsa
Unnamed #1
Unnamed #2
Unnamed *3
Unnamed 04
Morrison
—
—
Lower Main
Upper
(1) *6
C2) *7
(3) *8
—
--
Dllco and Gibson
Coals
(1) *1
(2) *2
(3) 13
—
Active Mine
—
~
—
~
—
(1K2M3) Navajo Mine
—
—
(1)(2)(3)(1) McKinley
Mine
—
—
Type"
—
—
—
—
S
—
—
S
—
—
Company
—
—
—
—
—
Utah Interna-
tional
—
—
Pittsburgh and
Midway Coal
Mining Co.
—
—
Numbers in parentheses refer to knowi seams actively mined in corresponding mines.
bS • strip mine; D - deep mine; C * captive mine
-------
Table C-3 (continued). COALFIELD IDENTIFICATION
U)
~J
\J1
New Mexico (cont
San Juan
San Juan
San Juan
San Juan
San Juan
San Juan
San Juan
San Juan
San Juan
San Juan
San Juan
San Juan
San Juan
San Juan
Cerrlllos
.)
Toadlena
Newcomb
Chaco Canyon
Charca Mesa
San Mateo
Standing Rock
Zuni
Crownpoint
South Mount
Taylor
East Mount
Taylor
LaVentana
Monero
Tierra
Amarllla
Rio Puerco
Cerrlllos
San Juan
San Juan
San Juan
McKlnley
McKlnley
McKlnley
McKlnley
Valencia
McKlnley
Valencia
Valencia
McKlnley
Sandoval
Rio Arrlba
Rio Arrlba
Sandoval
Santa Fe
District
18
18
18
18
18
18
17, 18
16
17
17, 18
18
18
18
18
18
Seams*
—
—
—
Cleary Coals
—
Dllco Coals
—
Gibson Coals
Dllco Coals
Gibson Coals
Dllco Coals
Cleary Coals
Allison Coals
—
—
Dllco Coals
Gibson Coals
Miller Gulch
Cook and White
White Ash
Active Mine
"
"~
"
~~
~—
~
~~
~"
—
~~
~~ '
Type"
"
"
.-
Company
•
"Numbers In parentheses refer to known seams actively mined In corresponding mines.
bS - strip mine; D - deep mine; C - captive mine
-------
Table C-3 (continued). COALFIELD IDENTIFICATION
Ui
-j
o\
State/Region
New Mexico (cont.
Raton
Una del Gat a
Tijeras
Carthage
Jornada del
Muerto
Engle
Sierra Blanca
Datil Mountain
North Dakota
Northwestern
northwestern
Field
)
Baton
Una del Qata
T1J eras
Carthage
Jornada del
Muerto
Engle
Sierra Blanca
Datll Mountain
Noonan-Klncald
IJlobe
Counties
col fax
Sandoval
Eernalillo
Socorro
Socorro
Sienna
Lincoln
Valencia
Catron
Socorro
Burke
Ward
Burke
District
17
18
17
IS
18
17
18
17, 18
21
21
Searasa
(1) York Canyon
Anchor Canyon
Cottomrood Canyon
Left Pork
Yankee
Tin Pan
Verne jo
Raton
Chimney Divide
—
—
Upper
Carthage, lower
—
—
—
—
(1) Nocnan-Klncald
Nlobe
Bonus
Active Mine
CD York Canyon Mine
—
—
__
—
—
—
—
Typeb
D
—
..
—
—
—
—
(1) Baukol Noonan Klne S
(1} Baukol *2
—
—
Company .
Kaiser S.teel
Corp.
__
__
..
—
...
—
—
Baukol Noonan
Inc.
Baukol Noonan
Inc.
—
s In parentheses refer to known Beams actively mined In correcpondlng mines.
bS • strip nine; D • deep mine; C * captive Bine
-------
Table C-3 (continued). COALFIELD IDENTIFICATION
uo
North Dakota (co
Northwestern
Northwestern
Northwestern
Southwestern
Southwestern
Southwestern
Southwestern
Southwestern
Southwestern
Southwestern
Southwestern
Southwestern
nt.)
Avoca
M and M
Velva
Washburn
Wilton
Renner's Cove
Hazen
Beulah - Zap
Stanton
Center
Dunn Center
Dickinson
Counties
Williams
Williams
Ward
McLean
Burlelgh
Mercer
Mercer
Mercer
Mercer
Oliver
Oliver
Dunn
Billings
Dunn
Stark
District
21
21
21
21
21
21
21
21
21
21
21
21
Seams
11
12
*3
12
(2) Coteau
Stanton
Wilton
Zap
Beulah Zap
(3) Zap
(14) Schoolhouse
Beulah
(5) Stanton, Lignite
local bed
Hazel
Kuether
(6) D
(7) E
Active Mine
—
(2) Velva Mine
(ll) Beulah Mine
(3) Indian Head Mine
(5) Glenharold •-
(6) (7) No. 2 Mine
Type"
—
S
S
s
s
s
—
Company
—
Consolidation
Coal Co.
Knife River Coal
Mining Co.
North American
Coal Co.
Consolidation
Coal Co.
Huskey
Industries
—
aNumbers in parentheses refer t
bS « strip mine; D - deep mine;
o known seams actively mined in corresponding mines.
C * captive mine
-------
Table C-3 (continued). COALFIELD IDENTIFICATION
UJ
--5
CO
State/Region
Field
North Dakota (cont.)
Southwestern
Southwestern
Oregon
Coos Bay
Eden Ridge
Rogue River
Eckley
John Day Basin
South Dakota
Bowman-Qascoyne
New Leipzig
Coos
Eden Ridge
Rogue River
Eckley
John Day
Upper Northwest
Counties
Slope
Bowman
Grant
Hettlnger
Coos
Coos
Curry
Jackson
Coos
Curry
Orant
Wheeler
Gilllam
Morrow
Umatllla
—
District
21
23
23
23
23
23
—
Seams8
(8) Harmon
—
Beaver Hill
D
E
H
J
Lockhart
Carter
Meyers
Anderson
—
—
—
—
Active Mine
(8) Gascoyne Mine
—
South Slough
Englewood
Rlverton
Lillian
—
—
—
—
. —
Typeb
S
?
?
?
1
—
—
—
—
Company
Knife River Coal
Mine Co.
__
9
1
1
1
—
lumbers In parentheses refer to known seams actively mined In corresponding mines.
S - strip mine; D « deep mine; C * captive mine
-------
Table C-3 (continued). COALFIELD IDENTIFICATION
OJ
-a
vo
State/Region
Utah
Southwestern
Southwestern
Southwestern
Central
Central
Central
Central
Central
Central
Field
Alton
Kalparowlts
Plateau
Kolab-Harmony
Ht . Pleasant
Sallna Canyon
Sterling
Wales
Wasatch Plateau
Boole Cliffs
Counties
Kane
Oar field
Kane
Garfleld
Iron
Washington
Kane
Sanpete
Sevier
Sanpete
Sanpete
Carbon
Emery
Sanpete
Sevier
Carb.on
Emery
District
20
"
20
20
20
20
20
20
20
20
Seams*
Smirl
Bald Knoll
Chrlstensen
Alvey
Rees
Lower
Upper
unnamed
(1) Ivle
—
(2) Hiawatha
(3) Castlegate "A"
(1) Blind Canyon
Bear Canyon
Watt is
Spring Canyon
( 5) Castlegate "B"
Kenilworth
Gllson
Rock Canyon
Active Mine
—
—
—
—
(1) Mine 11
—
Bee Hive Mine
Desert Mine
Browning Mine
(1) Deer Creek Mine
(2) Plateau Mine
(3) Swisher Mine
(2) King Mine
(5) (7) Carbon Fuel Mir
(6) Sunnyside *1 Mine
(6) Sunnyside *2 Mine
(8) Sunnyside 13 Mine
(9)(10) Castlegate Mi
Type"
—-
—
—
—
D
—
D
D
D
D
D
D
D
le D
C, D
C, D
C, D
le D
1
Company
~~
~—
—
—
Southern Utah
Fuel Co.
—
American Coal Co.
American Coal Co.
Browning Coal Co.
Peabody Coal Co.
Plateau Mining Co
Swisher Coal Co.
United States
Fuel Co.
Carbon Fuel Co.
Kaiser Steel Corp
Kaiser Steel Corp
Kaiser Steel Corp
North American
Coal Co.
"Numbers in parentheses refer to known seams actively mined in corresponding mines.
bS - strip mine; D - deep mine; C - captive mine
-------
Table C-3 (continued). COALFIELD IDENTIFICATION
uo
co
o
State/Region
Utah (cont.)
Central
-
Central
Eastern and
Northern
Eastern and
northern
Eastern and
Northern
Eastern and
Northern
Eastern and
Northern
Eastern and
Northern
Eastern and
Northern
Eastern and
Northern
Eastern and
Field
Counties
Book Cliffs (cont.)
Emery
Vernal
Henry Mountains
Sego
La Sal -
San Juan
Tabby Mountain
Coalville
Henrys Pork
Goose Creek
Lost Creek
Emery
Sevler
Ulntah
Wayne
Qarfield
Ulntah
Grand
Grand
San Juan
Wasatch
Duehesne
Summit
Ulntah
Box Elder
Morgan
District
- 20
20
2D
20
20
20
20
20
20
20
Seams
(6) Lower Sunnyslde
(7) Castlegate Sub 3
(8) Upper Sunnyslde
(9) C
(10) D
A
C
I
Frontier
Mesa Verde
Dakota
Ferron
Emery
Palisade
Ballard
Chesterfield
Carbonera
—
Frontier
Mesa Verde
Coalvllle
—
—
—
Active Mine
Type*
(5) Soldier Canyon Mine D
(6) Geneva Coal Mine
—
—
—
—
—
—
—
—
—
—
C, D
—
—
—
—
—
—
—
—
Company
Premium Coal Co.
U.S. Steel Corp.
—
—
—
—
—
—
—
—
aNumbers In parentheses refer to known seams actively mined In corresponding mines.
S - strip mine; D - deep mine; C - captive mine
-------
Table C-3 (continued). COALFIELD IDENTIFICATION
UJ
oo
Washington
Northern
Northern
Isaquah -
Grand Ridge
Isaquah -
Grand Ridge
What com
Skagit
Newcastle -
Grand Ridge
Cedar Mountain
What com
Skagit
King
King
District
23
23
23
23
Sea»sa
Bellingham fl
Blue Canyon
Lake What com
Bellingham 12
Onnamed
Unnamed
Unnamed
Onnamed
Cokedale
*2
*3
14
Bagley
May Creek
Muldoon
Dolly Varden
Jones
Cavanaugh 12
Jones
Discovery
Ryan *1
New Lake Youngs 12
Cedar Mountain *2
r.ttasLr Mountain *1
Active Mine
—
Typ."
—
—
Company
—
—
~ aNuMbers in parentheses refer to known seaas actively mined in corresponding nines.
bS - strip mine; D - deep mine; C - captive mine
-------
Table C-3 (continued). COALFIELD IDENTIFICATION
u>
00
ru
State/Region
Washington (cont
Isaquah -
Grand Ridge
Isaquah -
Grand Ridge
Isaquah -
Grand Ridge
Isaquah -
Grand Ridge
Qreen River
Field
.)
Renton
Tiger Mountain
Nlblock
Taylor
Green River
Counties
King
King
King
King
King
District
23
23
23
23
23
Seamsa
#2
Sprlngbrook
Sunbeam
Newenham
Springhaven
Sevier
11
n
in
15
12
13
tn
16
Unnamed
McKay
Gem
(1) Rogers *3
Ra«ensdale #3
Ravensdale #4
Ravensdale #5
Active Mine
—
—
t
—
C 1) ( 2) Rogers Mine
.-
Typeb
—
—
—
—
D
Company
—
—
—
—
Palmer Coking
Coal Co.
lumbers In parentheses refer to known seams actively mined In corresponding mines.
bS - strip mine; D - deep mine; C - captive mine
-------
Table C-3 (continued). COALFIELD IDENTIFICATION
U)
CO
oo
Washington (cont
,
Green River (cont.)
Wilkeson -
Carbonado
Wilkeson -
Carbonado
Pierce
District
•
23
Seams
Ravensdale 19
Fulton
(2) Franklin #10
Dale 14
Harris
Nancy #6
Big Seam
Blayne 12
Blayne #3
Wilkeson 11
12
#3
11
#5
#7
Carbonado 15
Carbonado 18
Morgan 17
Big Ben
Splketon 16
#7
18
110
f!2
Active Mine
—
Type"
~"~
Company
lumbers in parentheses refer to known seams actively mined in corresponding mines.
bS - strip mine; D - deep mine; C - captive mine
-------
Table C-3 (continued). COALFIELD IDENTIFICATION
OJ
CO
State/Region
Washington (cont.
Field
)
Wllkeson -
Carbonado (cont.)
Fairfax-Ashford Fairfax-Ashford
Centralia-
Chehalis
Centralia-
Chehalls
Counties
Pierce
Lewis
Thurston
District
23
23
Seams3
Melmont #1
11 M O
12 1/2
#3
Montezuma *1
" 12
" 15
" 16
Blacksmith
McNeill
Unnamed
Unnamed
Unnamed
Nlsqually
Tona 11
Upper Thompson
Golden Glow
Mendata
Lucas Creek
Lower Thompson
Big Dirty
Little Dirty
(3) Smith
Active Mine
Melmont *1
Melmont *5
Melmont *6
—
(3) (1) Centralia
Typeb
—
S
Company
Washington
Irrigation and
Development Co.
"Numbers In parentheses refer to known seams actively mined In corresponding mines.
strip mine; D - deep mine; C - captive mine
-------
Table C-3 (continued). COALFIELD IDENTIFICATION
00
01
Washington (cont
.)
Centralla-
Chehalls (cont.)
Morton
Eastern Lewis
County
Kelso Castle
Rock
''Numbers In p
Morton
Eastern Lewis
County
Kelso Castle
Rock
irentheses refer
Lewis
Lewis
Cowlltz
Lewis
o known seams
District
23
23
23
seam,a
Penltenlary
D & F
Tona 12
Black Bear
(1) Big
Unnamed
Unnamed
Unnamed
Unnamed
12
13
tn
Unnamed
Unnamed
Unnamed
Unnamed
Unnamed
Leavell
Cherry Creek
Unnamed
Unnamed
Walker
Silver Creek
Unnamed
Active Mine
—
—
Type"
~"~
—
Company
.
"
—
actively mined In corresponding mines.
bS - strip mine; D - deep mine; C - captive mine
-------
Table C-3 (continued). COALFIELD IDENTIFICATION
U)
oo
o\
State/Region
Field
Washington (cont.)
Kelso Castle
Rook (cont.)
Roslyn
Taneum-
Nanastash
Wyoming
Powder River
Basin
Powder River
Basin
Powder River
Basin
Powder River
Basin
Roslyn
Taneum-
Manastash
Dry Cheyenne/
Glenrock
Spotted Horse
Sheridan
Sussex
Counties
Kittitas
Klttltas
Converse
Campbell
Sheridan
Sheridan
Johnson
District
23
23
19
19
19
19
Seamsa
Schuff
Cedar Creek #1
Unnamed
Big Dirty *1
Big Dirty 13
Roslyn #5
Plant #6
Green 17
Wright *8
Unnamed
—
Badger
(1) School
P
Canyon
Felix
Smith
Carney
( 2 ) Monarch
Kleenburn
(3) Armstrong
Lower
Upper
Active Mine
—
—
(1) Dave Johnston
Mine
—
(2) (3) Big Horn Mine
—
Type"
—
s,c
~
s
—
..
—
Pacific Power I
Light Co.
~
Big Horn Coal Co.
—
Numbers in parentheses refer to known seams actively mined in corresponding mines.
S « strip mine; D - deep mine; C « captive mine
-------
Table C-3 (continued). COALFIELD IDENTIFICATION
U)
CO
State/Region
Wyoming (cont.)
PoMder River
Basin
Powder River
Basin
Powder River
Basin
Powder River
Basin
Powder River
Basin
Green Riv r
Green River
Field
Gillette
Powder River
Buffalo
Barber
Lost Spring
Little Snake
River
Great Divide
Basin - Red
Desert
Counties
Converse
Campbell
Johnson
Johnson
Converse
Carbon
Sweetwater
Carbon
District
19
19
19
19
19
19
19
Seams8
D
E
F
(4) Wyodak
Arvada
Pelii
Lower Olm
(5) Roland Smith
Healy
Dry Creek
Uorass
—
B
D
E
B
C
Battle 12
Battle *3
Creston 12
Creston #3
Hadsell *2
Sourdough - Monument
Tierney
Active Mine
—
(M)( 5) Belle-Ayr Mine
(5) Wyodak Mine
~~
~~
—
Type"
S
S
"
™
"""
"
—
Company
—
Amax Coal Co.
Wyodak Resources
Development Corp.
-• •
"
~
—
aNumbers in parentheses refer to known seams actively mined In corresponding mines.
bS - strip mine; D - deep mine; C - captive mine
-------
Table C-3 (continued). COALFIELD IDENTIFICATION
(JO
co
CO
State/Region
Wyoming (cont.)
Field
Green River (oont.)
Green River
Hanna Field
Outcrop
Hams Pork
Rock Springs
Hanna Field
Kemmerer
Big Horn Basin Gebo
Big Horn Basin Grass Creek
Counties
Sweetwater
Carbon
Lincoln
Hot Springs
Hot Springs
District
19
19
19
19
19
Seams
Jim Brldger
Latham #3
Latham #t
Cherokee
(6) Rock Springs #7
(7) Rock Springs #11
(8) #25
(9) Hanna t2
( 10) Brooks
(11) #65
(12) #80
(13) #82
#50
(lil)Adaville #1
#11
#7
Unnamed
Unnamed
Active Mine
.
(7) Rainbow #7
(6) Rainbow #8
(8) Seminol #1 Mine
(12) (13) Rosebud Mine
Rimrock No. 2
(10) Rimrock Strip Mine
(11) Vanguard No. 1
Rimrock No. 1
(9) Seminol #2 Mine
(111) Elkol Mine
(111) Sorensen Mine
—
—
Type"
D
D
S
S
S
S
D
S
S
S
S
—
—
Company
Gunn-Quealy Coal
Gunn-Quealy Coal
Arch Minerals
Corp.
Rosebud Coal
Sales Co.
Resources Explor-
ation & Mining
Inc.
Energy Develop-
ment , Inc .
Energy Develop-
ment , Inc .
Resources Explor-
ation I Mining
Inc.
Arch Minerals
Corp .
Kemmerer Coal Co.
Kemmerer Coal Co.
—
—
Numbers In parentheses refer to known seams actively mined IP corresponding mines.
S * strip mine; D * deep mine; C - captive mine
-------
Table C-3 (continued). COALFIELD IDENTIFICATION
Wyoming (cont.)
Miscellaneous
Miscellaneous
Miscellaneous
Miscellaneous
Miscellaneous
-
Qoshen Hole
Rock Creek
Jackson Hole
Wind River Basin
Black Hills
Region
Counties
Goshen
Albany
Teton
Fremont
Crook
District
19
19
19
19
19
Seamsa
—
—
—
—
—
Active Mine
— —
—
~~
—
—
Type"
""
~~
Company
.
aNumbers In parentheses refer to known seams actively mined In corresponding mines.
bS • strip mine; D - deep mine; C - captive mine
U)
00
-------
APPENDIX D
CURRENT UTILIZATION OP WESTERN COALS
BY USER TYPE
391
-------
Table D-l is a compilation of all known U.S. plants burning
coal or contemplating burning coal derived from states
included in this study. All data presented in Table D-l
originate from the 1973 Keystone Coal Industry Manual
published by McGraw-Hill.1
A total of 97 electric utilities burned western coal in
1972. Thirty-eight of these plants are located outside
of the western producing districts. Thirteen industrial
plants burned western coal in 1972. Two of these plants
are located outside of the western producing districts.
393
-------
Table D-l. COAL BURNING PLANTS-ELECTRIC UTILITY1
VQ
Ul
State
Arizona
Colorado
Illinois
Indiana
Iowa
Utility Company
Arizona Public Service Co.
Public Service Co. of N. Hex.
Salt River Project
Colorado Springs, Dept.
Public Utilities
Colorado Ute Elec. Assn.
Port Collins Light 4 Power
Public Service Co. of Colo.
Southern Colorado Power
Div. Central Telephone &
Utilities Corp.
Walsenburg Utilities
Western Colorado. Power Co.
Commonwealth Edison Co.
Commonwealth Edison Co. of
Indiana
Iowa Electric Light & Power
Iowa Power and Light Co.
Iowa Public Service Co.
City
Joseph City
Page
Phoenix
Colorado Sp.
Nucla
Hayden
Ft. Collins
Boulder
Denver
Alaraosa
Denver
Cameo
Pueblo
Canon City
Walsenburg
Montrose
Durango
Chicago
Chicago
Waukegan
Jollet
Pekin
Dlxon
Hammond
Iowa Palls
Marshalltown
Council
Bluffs
Des Moines
Eagle Srove
Sallx
Plant
Cholla
San Juan
NavaJ o
Drake Steam
Nucla
Hayden
Tonnage Utilized & Source of Coal
348,000 T,. (1972) N.M.
Under Construction
Under Construction
100,000 T. (1972) ?
75,000 T (1972) Colo.
577,000 T. (1972) Colo.
Light & Power 5,100 T. (1972) Colo.
Dept.
Valmont Steam 210,000 T. (1971) ?
Arapahoe
Alamosa
Cherokee
Cameo Steam
Comanche
Pueblo
W. N. Clark
City
Walsen
Jim Bullock
Durango
Pisk
Crawford
Waukegan #1
Jollet
Powerton
Dixon
State Line
Iowa Falls
Sutherland
Council
Bluffs
Des Moines
No. 2
Eagle Grove
George Neal
285,000 T. (197D Colo., Wyo.
1,300 T. (1971) 1
1,550,000- T. (197D ?
130,000 T. (1971) Colo.
Under Construction
2,100 T. (1972) ?
83,000 T. (1972) Colo.
13,000 T. (1971) ?
1)3,000 T. (1971) Colo.
2,000 T. (1971) Colo.
720,000 T. (1972) Mont., Wyo.
930,000 T. (1972) Mont., Wyo.
2,131,000 T. (1972) 111., Ky.,
W., Wyo.
3,819,000 T. (1972) 111., Mont.
1, lit, 000 T. (1972) Mont., 111.
291,000 T. (1972) 111., Ind., Ky.,
W., Wyo.
2,192,000 T. (1972) 111., Ind.,
Mont., Wyo.
2,000 T. (1972) ?
193,000 T. (1972) ?
278,000 T. (1972) Wyo.
524,000 T. (1972) Iowa, Mo., Wyo.
2,330 T. (1972) ?
688,970 T. (1972) Wyo.
-------
Table D-l (continued). COAL BURNING PLANTS-ELECTRIC UTILITY1
UJ
V£>
CT\
State
Iowa
Minnesota
Missouri
Montana
Nebraska
Nevada
New Mexico
Utility Company
Iowa Public Service Co.
Hibblng Public Utilities
Conun •
Minnesota Power & Light Co.
Moorhead Public Service Dept.
Otter Tail Power Co.
Northern States Power Co.
Kansas City Power & Light Co
Montana-Dakota Utilities Co.
Montana Power Co.
Fremont Dept, of Utilities
Nebraska Public Power Dlst.
Lincoln Electric System
Omaha Public Power Dist.
Nevada Power Co.
Southern California Edison
Arizona Public Service Co.
Public Service Co. of N. Hex.
Raton Public Service Co.
City
Storm Lake
Hibbing
Duluth
Aurora
Cohasset
Moorhead
Fergus Palls
Ortonville
Granite
Palls
Mankato
Minneapolis
St. Paul
Red Wing
Wlnona
Kansas City
Sidney
Billings
Colstrlp
Fremont
Hal lam
Bellevue
Lincoln
Omaha
Omaha
Moapa
Laughlin
Fruit land
Fruit land
Raton
Plant
Kawkeye
Hibbing
M.L. Hlbbard
S.E.
Aurora S.E.
Clay Boswell
Moorhead
Hoot Lake
Ortonville
Minnesota
Valley
Wilmarth
Riverside
High Bridge
Red Wing
Winona
Hawthorn
Lewis & Clark
J.E. Corette
Colstrip
Fremont
Sheldon
Kramer
Lincoln
N. Omaha
Jones Street
Reid Gardner
Mohave
Four Comers
San Juan
Raton
8,880 T. (1972) 1
100,000 T. (1972) Mont.
361,000 T. (1972) W. Va., Mont.
352,000 T. (1972) Mont.
597,000 T. (1972) Mont.
3,636 T. (1972) N.D.
700,000 T. (1972) N.D.
100,000 T. (1972) N.D.
96,000 T. (1972) 111., Kans., Ky.,
N.D.
30,000 T. (1972) N.D., Mont.
9*2,000 T. (1972) HI., Ky., W. , Mont.
500,000 T. (1972) 111., Ky. (W),
Mont., Okla.
32,000 T. (1972) N.D.
30,000 T. (1972) 111., N.D.
1,025,600 T. (1972) Mo., Kans.,
Okla . , Wyo .
320,000 T. (1972) ?
149,000 T. (1972) 1
Under construction
35,000 T. (1972) Kans., Wyo.
251,800 T. (1972) ?
Ill6,000 T. (1972) Kans., Colo.
'lOO T. (1971) ?
7^3,110 T. (1972) Kans., Wyo.. Mo.,
Okla.
29,300 T. (1972) ?
600,000 T. (1971) Utah
2,910,000 T. (1972) Ariz.
6,893,000 T. (1972) N.M.
Under construction
24,000 T. (1971) N. Hex.
-------
Table D-l (continued). COAL BURNING PLANTS-ELECTRIC UTILITY1
UJ
State
N. Dakota
S. Dakota
Utah
Washington
Wisconsin
Utility Company
Basin Electric Power Coop.
Central Power Elec. Coop.
Minnkota Power Coop.
Montana-Dakota Utilities Co.
Northern States Power Co.
Otter Tail Power Co.
United Power Association
Valley City Electric & Water
Works
Black Hills Power & Light Co.
Montana-Dakota Utilities Co.
Northern States Power Co.
Northwestern Public Service
California Pacific Utilities
Provo Water and Power Dept.
Utah Power & Light Co.
Pacific Power & Light Co. &
Washington Water Power Co.
Dairy land Power Cooperative
Northern States Power Co.
Wisconsin Electric Power Co.
City
Stanton
Velva
Center
Grand Forks
Beulah
Mandan
Minot
Devils Lake
Jamestown
Wahpeton
Stanton
Valley City
Lead
Rapid City
Mobridge
Sioux Falls
Aberdeen
Mitchell
Cedar City
Provo
Salt Lake C.
Castle Gate
Or em
Huntlngton
Centralia
Alma
Genoa
La Crosse
Oak Creek
Plant
Leland Olds
Wm. J. Neal
Milton R.
Young
Franklin P.
Wood
Beulah
R.M. Heskett
Bison
Devils Lake
Jamestown
Kidder
Stanton
Valley City
Kirk
Ben French
Mobridge
Lawrence
Aberdeen
Mitchell
Cedar Stream
Provo City
Gadsby
Carbon Steam
Hale
Huntington
Canyon
Centralia
Alma
Genoa
French Island
Oak Creek
Tonnage Utilized & Source of Coal
1,316,000 T. (1972) ?
205,000 T. (1972) ?
1,620,000 T. (1972) 1
4,000 T. (1972) ?
102,000 T. (1972) N.D.
570,000 T. (1972) N.D.
1(1,000 T. (1972) N.D.
67,000 T. (1972) N.D.
57,000 T. (1972) N.D.
20,000 T. (1972) N.D.
862,000 T. (1972) ?
18,979 T. (1972) Beulah Dist. of
N.D.
101,000 T. (1971) Wyo.
103,000 T. (1971) Wyo.
15,000 T. (1972) N.D.
50,000 T. (1972) Mont., Okla., Kans
20,000 T. (1972) Wyo.
20,000 T. (1972) Wyo.
9,930 T. (1971) Utah
13,313 T- (1972) Utah
32,000 T. (1971) Utah
371,000 T. (1971) Utah
1,000 T. (1971) Utah
Under construction
2,003,000 T. (1972) Wash.
565,000 T. (1971) 111., Ky., W.,
Ark., Mont.
725,000 T. (1971) 111., Ky., W.,
Ark. , Wyo.
12,000 T. (19T2) N.D.
3,262,000 T. (1972) 111., Ky., W.,
Ind. , Wyo.
-------
Table D-l (continued). COAL BURNING PLANTS-ELECTRIC UTILITY1
State
Wyoming
Utility Company
Black Kills Power & Light Co.
Montana-Dakota Utilities Co.
Pacific Power 4 Light Co.
Utah Power & Light Co.
.
City
Osage
Wyodak
Sheridan
Ke merer
Glenrock
Rock Springs
Plant
Osage
Neil Simpson
Unassigned
Acme
Naughton
Dave Johnstoi
Jim Brldger
Tonnage Utilized & Source of Coal
220,000 T. (1971) Wyo.
203,000 T. (1971) Wyo.
Under construction
30,000 T, (1972) Wyo.
Under construction
1.13MOO T. (1971) ?
2,600,000 T. (1972) ?
Under construction
OJ
MD
CO
'pp. 345-391.
-------
Table D-2. COAL BURNING PLANTS-INDUSTRIAL1
State
Company
City
Plant
Tonnage Utilized S Source of Coal
Colorado
Idaho
Illinois
Iowa
Oregon
Utah
American Crystal Sugar Co.
Great Western Sugar Co.
Ideal Cement Co.
Amalgamated Sugar Co.
Bunker Hill Co.
Monsanto Co.
General Motors Corp.
Clinton Corn Processing Co.
Amalgamated Sugar Co.
Marblehead Lime Co.
Ideal Cement Co.
Denver
Denver
Ft. Collins
Twin Palls
Nampa
Rupert
Kellogg
Soda Springs
La Grange
Clinton
Nyssa
Grantsvilla
Morgan
Boettcher
Twin Falls
Nampa
Mini-Cassia
Lead Smelter
Soda Springs
115,000 T. (1971) ?
404,091 T. (197D ?
19,000 T. (1972) ?
40,000 T. (1972) Utah
67,000 (1972) Utah, Wyo.
51,000 T. (1972) Utah, Wyo.
36,000 T. (1971) Utah, Wyo., Brit,
Col.
20,000 T. (1972) Wyo.
Electro-Motive 55,000 T. (1971) Ky., Utah
Div.
Clinton
Nyssa
Delle
332,000 T. (197D 111., Ky., Wyo.
53,000 T. (1971) Utah, Wyo.
30,000 T. (1972) Utah
Devil's Slide 14,000 T. (1972) ?
. 304-335.
-------
APPENDIX E
COAL PRICES F.O.B. MINE
BY COUNTY FOR 1972
-------
Table E-l. PRODUCTION, SHIPMENTS, AND VALUE AT BITUMINOUS COAL AND
LIGNITE MINES, IN 1972, BY STATE AND COUNTY22
(thousand short tons)
-pr
o
U)
State and county
Arizona:
tfevajo
Colorado:
Delta
FrtsnorA
Oarfteld
Gunnlson
Huerfano
LaPlata
Las Anbnas
Mesa
Noffat
Montrose
Pltkln
Rio Blanco
Routt
VteM
Tbtal or average3
Montana (bltunlnous):
Big Ham
Misselshell
Rosebud
•total or averaes0
Montana (Uarite):
Powder River
RtcrOand
Total or avera@sc
Under
Nmfcer
or mines
-
3
5
1
4
1
1
1
1
2
_
3
1
1
3
27
—
3
3
_
_
_
Total or average Montana0 3
New Mexico:
Colfax
McKlnley
San Juan
Total or average0
North Dakota (ligilte):
Mams
Bowman
Burke
Grant
Wclean
Mercer
Oliver
Stark
Ward
WilliaiTB
Total or average0
1
_
_
1
_
_
_
_
_
_
_
_
_
_
-
pround
Quantity
-
98
78
1
719
ll
7
616
11
291
649
5
12
575
3,070
_
17
-
17
•
_
_
17
1.014
_
_
1,014
_
_
_
_
_
_
_
_
_
.
-
Production
Strip
Nurber
of mines
1
_
2
_
-
-
1
-
-
_
1
-
-
4
—
8
1
1
2
4
1
1
2
6
1
2
1
11
2
1
2
I
1
3
1
1
1
1
11
Quantity
2,954
_
136
_
-
tl
—
—
_
93
-
2,219
_
2,452
772
9
7,102
7,882
3
320
322
8,204
17
402
6,816
7,235
19
166
487
3
16
3,148
2,278
117
393
5
6,532
A
Nurber
of mines
-
_
_
_
-
-
-
-
-
_
_
-
-
-
_
-
-
-
-
-
—
-
-
-
-
-
_
-
_
.
_
_
_
_
_
-
_
-
"
wer
ftjantitv
-
_
_
.
_
-
_
_
—
_
_
-
_
_
_
-
-
-
-
-
-
-
_
-
—
_
_
-
_
_
-
-
_
_
_
-
-
-
-
Shipments
Rail or
natei*
-
90
a
690
-
_
616
_
260
_
6*9
-
1,642
272
4.221
772
-
7,101
7,873
-
320
320
8,193
1,030
397
1,427
_
118
457
_
_
2,152
_
-
196
-
3,224
Truck
-
8
213
1
28
4
11
.
-
3^
93
5
13
301
712
—
25
1
26
2
e
2
2B
—
5
5
19
30
3
16
13
117
-
5
203
Ktne-
mouth
generating
plants
-
_
_
_
_
_
_
_
11
_
_
-
-
575
587
—
—
-
-
-
_
_
-
-
-
6,816
6,816
_
_
-
.
_
582
2,278
-
196
-
3,157
All.
othei^
2,95^
e
e
_
_
_
-
_
e
_
_
_
e
1
2
—
_
—
_
_
_
_
-
-
—
_
-
_
it8
-
-
_
e
-
-
-
-
«8
Brtal0
2,954
98
a4
i
719
4
11
616
11
294
93
6*9
5
2,231
575
5,522
772
25
7.102
7,899
2
320
322
8,221
1,030
402
6,816
8.248
19
166
487
3
16
3,148
2,278
117
393
5
6,632
Average
value .
Vf
<11.53
4.B8
w
9.59
7.51
4.30
6.0
4.03
5.17
6.45
w
w
M
2.01
V
w
2.1)5
2.03
w
3.6
2.02
-------
Table E-l (continued). PRODUCTION, SHIPMENTS, AND VALUE AT BITUMINOUS COAL
AND LIGNITE MINES, IN 1972, BY STATE AND COUNTY22
(thousand short tons)
4=-
O
State and county
Utah:
Carbon
Bierj
Sevier
Sumalt
Dotal or average0
Washington:
»i«
Lewis
Total or average0
Hycolng:
Canjibell
Carbon
Converse
W* Springs
Lincoln
Steri&n
Sneetwter
Total or average0
Ibtal or average for
Kilted States
FiXjduuulud
UrtierKPOuntl
te*er
f mines
11
8
1
1
21
1
1
1
2
2
5
1,996
(juantlty
3,012
1,569
184
6
1,770
29
29
335
6
_101
142
301,103
Strip
Number
of mines
1
1
2
2
2
4
2
2
2
1
13
2,309
Quantity
32
32
2.606
2.606
656
3,843
2,622
2,103
974
m.
10,187
275,730
Aw
Hu.ter
of mines
-
-
i
574
5er
Quantity
-
-
-
15,554
Shipments
Ball or
water*
2,746
1,085
16
8,877
447
1,15*
e
259
934
3%
6,149
463,839
Truck
296
484
138
923
29
a
38
10
24
5
10
1
80
65,633
mne-
mouth
generating
plants
_
2.597
2,597
198
2,618
1,844
4,660
61,878
All .
otherb
2
2
1
4
e
31
39
1,036
tttal5
3.0W
1,569
184
6
I) ,802
29
2.606
2,634
656
1,179
2,622
6
2,103
971
ffi
10,928
595,336
Average
value A
per ton
no.i3
6.90
6.50
5.50
8.93
16.40
6?1
6.61
w
3.89
3.46
10.21
x
w
3.74
7.66
"withheld to avoid disclosing Individual company data.
S3ncli*les coal loaded at mine directly Into rellroed cars or river barges, hauled by trucks to railroad sidings, and hauled by trucks to waterways.
blnclu*«s coal used at nine for power and heat,
Into beehive coke at mine, used by mine employees, used for all other purposes at mine and
shipped by slurry pipeline In Arizona.
cData way not add to totals shorn because of ludependsit rounding.
'Value received or chared for coal f.o.b. nine. Includes a value for coal not sold but used by producers, such as mine fuel and coal coked, as
estimted by producers at average prices that ntf#it have been received if such coal had been sold conraercially.
eLess than 500 tons.
Z2PP- 3*7-355-
-------
APPENDIX P
FEDERAL AND STATE SURFACE MINING LEGISLATION
405
-------
A summary of regulations concerning surface mining in force
as of 1972 is included in this Appendix. The regulations
for federally owned lands are shown in Table F-l. The state
laws are summarized in Table F-2. States possessing no
regulations per se in 1972 were Arizona, New Mexico, Oregon,
South Dakota, and Utah. Normally states and areas not
having specific laws fall under Indian agreements or
federal jurisdiction. The continuous flux of surface mining
legislation is realized and as such more current legislation
should be investigated on a case by case basis.
407
-------
Table F-l. A SUMMARY OP THE REGULATIONS GOVERNING
SURFACE MINING ON LANDS UNDER THE JURISDICTION OF THE
U.S. GOVERNMENTS,2
Law and date
Minerals subject to
Regulating agency
Permit requirements
Basic fee
Additional
Penalty for failure
to comply
Code of Federal Regulations.
Title 43, Part 23, January 18, 1969,
and Title 43, Part 3501.1-4(b) (1),
June 13, 1970. The Mineral Leasing
Act of February 25, 1920, as amended
and supplemented (30 U.S.C. 181-287),
the Mineral Leasing Act for Acquired
Lands (30 U.S.C. 351-359), and the
Materials Act of July 31, 1947, as
amended (30 U.S.C. 601-604).
All leasable or salable minerals
owned by the U.S. Government.
The District Manager, Bureau of Land
Management, in cooperation with the
Federal agency having jurisdiction
over the land, if appropriate, and
in consultation with the Regional
Mining Supervisor, U.S. Geological
Survey, and, if necessary, in
consultation with the Federal Water
Quality Administration, and in
consultation with the private owners
of the surface rights, if appropriate.
Each application for permit, lease,
or license must be accompanied by a
service charge of $10.
A minimum annual rental of 25 cents
per acre for the first year, 50 cents
per acre for the second through the
fifth years, and $1 per acre there-
after. Each permit may include up to
5,120 acres. An individual or cor-
poration may hold up to 46,080 acres
in permits or leases.
Failure of an operator to comply with
the terms of a permit or lease shall
be cause for the Mining Supervisor or
District Manager to take action to
cancel the permit or lease and for-
feiture of bond.
409
-------
Table P-l (continued). A SUMMARY OF THE REGULATIONS
GOVERNING SURFACE MINING ON LANDS UNDER THE JURISDICTION
OF THE U.S. GOVERNMENT
Bond requirements:
Minimum
Additional
$2,000. In lieu of a performance
bond, the operator may deposit cash
or negotiable bonds of the U.S. Govern
ment. ^vexn-
The amount of the bond shall be
sufficient to satisfy the reclamation
requirements of an approved minins:
plan. &
Backfilling and
grading
Reclamation requirements:
Plan required Yes, to be filed with the Mining
Supervisor and outlining the minine;
operation and the measures to be
taken to protect the environment and
eliminate any hazards to health and
safety.
The mining plan shall show the
proposed methods and timing of gradine-
and backfilling of the areas affected
by the mining operation. The mining
plan is subject to review and approval
by the Mining Supervisor or the
District Manager. Mutual acceptance
of a mining plan is binding on the
part of the operator. The mining plan
may be amended if warranted by unfore-
seen circumstances.
If stipulated in the permit, lease or
contract, the mining plan shall show
the method of preparing and fertilizine-
the soil, and the types and mixtures of
grasses, shrubs or trees, and the
amount, per acre.
Substitution of lands No.
permitted
Mining and reclamation Within 30 days of the end of each
reports calendar year, or within 30 days of
the cessation of operations, the
operator shall file with the Mining
Supervisor a description of the oper-
ation, including the area affected
Replanting
JJ10
-------
Table P-l (continued). A SUMMARY OP THE REGULATIONS
GOVERNING SURFACE MINING ON LANDS UNDER THE JURISDICTION
OP THE U.S. GOVERNMENT
and the area reclaimed, the method of
reclamation and results, and the
reclamation yet to be done.
Penalty for failure to reclaim:
Bond forfeiture Yes, for failure to comply with the
surface protection and reclamation
aspects of an approved mining plan.
Denial of new permit
Yes, for forfeiture of bond unless
the disturbed land has been subse-
quently reclaimed without cost to the
Federal Government.
aApplies principally to Alaska, Arizona, California, Idaho,
Montana, Nevada, New Mexico, North Dakota, Utah, Washington,
and Wyoming.
411
-------
Table F-2. SUMMARY OF THE LAWS REGULATING STRIP
MINING IN THE UNITED STATES, BY STATES2
Arizona
Law and date
Regulating agency
Colorado
Law and date
Minerals subject to
Regulating agency
License requirements
Basic fee
Additional
Penalty for failure
to comply
Bond requirements:
Minimum
Additional
None.
Regulated by Federal law applying to
the Navajo and Hop! Indian Reserva-
tions. Individual agreements are
made between the coal producers and
the tribe concerned.
Colorado Open Cut Land Reclamation
Act of 1969.
Coal.
Colorado Department of Natural
Resources.
$50.
None.
No legal obligation other than that
provided in the contract agreement.
$2,000 for mining on Indian lands
or the public domain - Federal
requirement.
Not to exceed $100 per acre of
disturbed land.
Reclamation requirements:
Plan
Backfilling and
grading
Replanting
Only after mining is completed. Maps
are required.
Exposed face of seam must be covered
by at least 2 feet of earth or spoil
or by at least 2 feet of water.
Strike off ridges to minimum top
width of 10 feet; strike off peaks
to a minimum of 15 feet; impound
water. Grade to a rolling topography
operator shall provide access roads. '
Operator may reclaim land for forest
range, crop, or other use in *
cooperation with the state.
-------
Table F-2 (continued). SUMMARY OP THE LAWS
REGULATING STRIP MINING IN THE UNITED STATES, BY STATES
Montana
Law and date
Minerals subject to
Regulating agency
License requirements
Basic fee
Additional
Penalty for failure
to comply
Bond requirements:
Minimum
Additional
Chapter 245, 1967 Session Laws
Coal.
Montana Bureau of Mines and Geology
$0.05 per ton tax on excess of
50,000 tons.
None.
A contract agreement prevails between
the State and the operator.
None.
None.
Reclamation requirements:
Backfilling and
grading
New Mexico
Law and date
Minerals subject to
North Dakota
Law and date
Minerals subject to
Regulating agency
License requirements
Reclamation costs are extended as
credit toward paying the coal mines
license tax.
None.
On Indian lands, mining is in accord-
ance with the individual agreement
between the operator and the Indians.
Chapter 38-01 through 14 . North
Dakota Century Code. Effective 1919,
as revised. Reclamation of Strip
Mined Lands, Chapter 38-14, January 1,
1970, and amended July 1, 1971.
Any mineral where the overburden
exceeds 10 feet in depth.
State Mine Inspector (mining);
Public Service Commission
(reclamation)
$5 annually for 100 tons or less;
$15 for 101 to 1,000 tons; $45 for
1,001 to 5,000 tons; $65 for 5,001
413
-------
Table P-2 (continued). SUMMARY OP THE LAWS
REGULATING STRIP MINING IN THE UNITED STATES, BY STATES
North Dakota (continued)
to 10,000 tons; $85 for 10,001 to
20,000 tons; $125 for 20,001 to
50,000 tons; $200 for 50,001 to
200,000 tons; $300 for more than
200,000 tons.
Permit requirements
Penalty for failure
to comply
Bond requirements
Permit term is for 3 years. For 10
acres or less, $25 and an amount
equal to $7.50 times the number of
acres affected. For 11 to 50 acres
$100 and an amount equal to $3.50 '
times the number of acres. For over
50 acres, $275 and an amount equal
to $2.50 times the number of acres
Permit applications shall describe*
the area and the estimated acreage
to be affected in the following 3
years, Permits may be amended.
Extensions may be granted on an
annual basis.
Willful neglect or violation of the
regulations is a misdemeanor punish-
able by fine or imprisonment, or
both, to the extent of $500 or 6
months in jail.
$200 per acre of land mined, or
fraction thereof, where the over-
burden exceeds 10 feet.
Reclamation requirements:
Plan
Required. A plan and map shall be
submitted not later than the first
day of December following date of
the mining permit. The plan and
approval thereof are subject to the
advice of other agencies and persons
having experience in reclamation.
The plan must designate the intended
future use of the disturbed area.
The landowner is granted the option
of determining the method of
reclamation.
-------
Table F-2 (continued). SUMMARY OP THE LAWS
REGULATING STRIP MINING IN THE UNITED STATES, BY STATES
North Dakota (continued)
Backfilling and Depends on the proposed future use.
grading For crops and hay, peaks and ridges
graded and valleys filled to extent
necessary to enable the traverse of
farm machinery. For pasture, peaks
and ridges must be struck off to
minimum width of 35 feet. For forest
planting, peaks and ridges are to be
struck off to a minimum width of
35 feet. Negotiable access roads
must be provided. Earth dams must
be provided to prevent runoff except
that lakes and ponds shall not
interfere with mining. Land within
660 feet of, and visible from any
public road, building, or cemetery
must be graded to a rolling topography
with slopes of not more than 20
percent grade.
Replanting Bond or other surety may be forfeited
for failure to comply with the
reclamation plan. However, two
plantings or seedings relieve the
miner from further obligations,
regardless of success or failure of
the planting efforts.
Mining and reclamation The operator shall submit by
reports September 1 of each year of the
permit term, a map showing pit
location with a description of the
land affected.
Substitution of lands Not permitted.
Penalty for failure
to reclaim:
Bond forfeiture Bond is forfeited. No new permits
will be issued and all other mining
operations in North Dakota must cease
in 30 days. The Commission has the
authority to reclaim any affected
land on which a bond has been for-
feited.
-------
Table F-2 (continued). SUMMARY OF THE LAWS
REGULATING STRIP MINING IN THE UNITED STATES, BY STATES
Utah
Law and date
Regulating agency
Washington
Law and date
Minerals subject to
None.
Regulated by Federal laws, enforced
by the Industrial Commission of Utah
and the Utah State Division of Health.
Title 76, RCW, January 1, 1971
All in which more than 10,000 tons
are produced in 1 year, or which
newly disturbs more than 2 acres of
land in 1 year.
Mining and reclamation Operator is required to file an
reports activities report within 30 days
after the completion of mining, or
within 30 days of the anniversary
of the operating permit, whichever
is earlier.
Penalty for failure
to reclaim:
Bond forfeiture
Regulating agency
License requirements
Basic fee
Additional
Penalty for failure
to comply
Bond requirements:
Minimum
Bond forfeited if reclamation is not
completed within 2 years of the
completion of mining. New permit
denied for failure to complete the
required reclamation work.
Board of Natural Resources.
$25 per year per separate mining
operation.
$5 per acre for the excess over 10
acres disturbed during the previous
year.
Operating without a permit is a
gross misdemeanor. Each day of such
operation constitutes a separate
violation.
Not less than $100 per acre. Cash,
savings, or other suitable securities
may be substituted in lieu of bond.
416
-------
Table F-2 (continued). SUMMARY OP THE LAWS
REGULATING STRIP MINING IN THE UNITED STATES, BY STATES
Washington (continued)
Additional The estimated cost of reclaiming
that area to be disturbed during the
next 12 months plus any area for
which a permit has been issued and
the reclamation not completed. The
amount shall not exceed $1,000 per
acre or fraction thereof.
Reclamation requirements:
Plan Required. It should state the
proposed subsequent use of the land,
method of restoration, revegetation,
water control, and the prevention of
hazards,
Backfilling and
grading
Replanting
Wyoming
Law and date
Minerals subject to
Regulating agency
License Requirements
Basic fee
Additional
Penalty for failure
to comply
Bond requirements:
Minimum
Spoil banks shall be reduced to a
gently rolling topography. Banks of
pits shall be sloped. Quarry walls
shall be stepped or backfilled to
eliminate any hazards. Drainage
shall be provided for surface waters
and all acid-forming material shall
be covered by clean fill.
Vegetative cover is required
commesurate with the future use of
the restored land.
Open Cut Land Reclamation Act,
May 23, 1969.
All underlying sufficient overburden
to require disturbing the cover.
Commissioner of Public Lands.
$50.
None.
$1,000. Each operating day is con-
sidered a separate offense.
Depending on the acreage disturbed
and that reclaimed in the past year,
the amount of bond may be set by the
417
-------
Table P-2 (continued). SUMMARY OP THE LAWS
REGULATING STRIP MINING IN THE UNITED STATES, BY STATES
Wyoming (continued)
Commissioner in an amount sufficient
to reclaim the land. Cash or other
security may be posted in lieu of
bond.
Reclamation requirements:
Plan Reclamation plan is required, with
mine map.
Backfilling and
grading
Replanting
Exposed seams may be covered to a
depth of at least 2 feet. Peaks and
ridges must be reduced to a rolling
topography. Dangerous effluent must
be impounded.
Replanting is required in conformance
with the recommendations by the Soil
Conservation Service and compatible
with the surrounding area.
Mining and reclamation Must be filed annually, and may be
reports followed by inspection.
Substitution of lands May be permitted at the discretion of
the regulating agency.
Penalty for failure
to reclaim
Bond will not be released until
reclamation is completed. New permit
may be denied. On Federal Land, the
Bureau of Land Management may permit
the operator the option of complying
with the State regulations rather
than with those stipulated by the
U.S. Government.
418
-------
APPENDIX G
COAL ANALYSES BY COUNTY AND MINE
A19
-------
The data presented in this appendix represent a compilation
of available state and federal reports. Data is presented
by state with the furthest subdivision being the coalfield,
town or mine from which the coal originated. The data is
principally transcribed "as is" and nonalphabetized from
the various sources with the objective being to present as
much data as possible in the shortest amount of time.
The data in Table G-l is arranged principally in the format
utilized in federal government tipple analyses. All per-
centage figures are on % by weight basis. Moisture % is on
an "as received" basis. Remaining proximate and ultimate
analysis data are for dry coal. Calorific value is listed
as either Btu per pound of "as received" coal or Btu per
pound of dry coal. Ash softening temperature, more commonly
called the fusion temperature of the ash, is given wherever
possible. This temperature is related to that at which the
fuel ash shows a greatly accelerated tendency to mass
together and stick in large quantities to heat absorbing
surfaces. It was unclear from the reports reviewed whether
or not the fusion temperature was reported under reducing
or oxidizing atmosphere conditions. The atmosphere under
which the test is conducted can affect the magnitude of the
temperature reading. It is assumed that a-1 ash softening
temperatures reported in this appendix are recorded under
reducing conditions as this is common practice. Free
swelling index indicates closely the coking characteristics
of bituminous coal when burned in fuel beds. Those analyses
reporting this figure tend to indicate that the coal is
coking. Hardgrove grindability index is reported wherever
possible to indicate the relative grindability or ease of
pulverizing coals in comparison with a coal chosen as having
a grindability of 100.
-------
The following is a list of bibliography references used to
compile the above information which correspond numerically
to those shown after each state name in Table G-l: 8 > 1 "»,
147,48, 101,102,103,10^
422
-------
Table G-l. WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
County
Navajo
Coal
field
or
town
Black
Mesa
Rayenta
Mine
Date
of
analy-
Nane sis
Black 1973
Mesa
No. 01
Proximate Ultimate
analysis, * analysis, '
%
3 $ 1 -s 1 i i s
Seam £. £ £ £ n £ 5 *:
ARIZONA1*7
Uncor- 11.7 14.4 47.1 8.5 0.4 5-1 70.3 1.1
related
Ash
gjj Btu softening Free
& as Btu terapera- swelling
& received dry ture,F° index
11.6 10,900 12,340 2,180
Hardgrove
grtndability
index
43
IX)
00
COLORADO1".".1'8,101,1''2
Weld
Erie
Eagle 1917
1917
" 1917
" 1917
" 1949
1950
" 1950
Imperial 1917
1917
" 1947
" 1948
1950
1917
1918
1950
Morrison 1918
1918
1948
" • 19149
22.6
22.1
22.4
22.3
20.0
21.8
20.8
23.3
23.0
22.5
22.8
20.9
22.0
23.0
22.5
21.1
22.7
22."^
21.1
18.5
39-8
40.0
Si, 4
38.7
38.1
38.8
38.6
39.2
40.2
40.3
40.0
41.8
39-5
40.8
38.4
39-0
39.6
39.6
38.6
39-1
55-5
54.7
53.4
53-7
54.4
54.2
54.3
54.8
53.8
53.3
54.8
52.4
54.8
52.8
55-3
54.8
52.4
52.1
53.0
52.9
4.7
5-3
5-2
7-6
7.5
7-0
7.1
6.0
6.0
6.4
5.2
5-8
5.7
6.4
6.3
6.2
8.0
8.3
8.4 '
8.0
0.4
0.3
0.3
0.4
0.5
0.4
0.5
0.4
0.3
0.4
0.4
0.3
0.4
0.6
0.5
0.5
0.6
0.4
0.6
0.4
74.0 1.6 11.4
4.9 73-5 1-6 14.4
4.7 70.2 1.6 14.9
9,860
9,850
9,830
9,550
9,810
9,640
9,710
9,660
9,670
9,690
9,780
9,880
9,770
9,580
9,660
9,820
9,380
9,460
9,540
9,890
12,730
12,650
12,660
12,290
12,260
12,330
12,260
12,580
12,550
12,500
12,660
12,500
12,520
12,430
12,460
12,450
12,140
12,150
12,090
12,140
2,080
2.0SC
2,050
2,130
2,050
2,040
2,050
2,140
2,140
2,080
2,100
2,090
-
2,050
2,040
2,010
2,210
2,280
2,220
2,180
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
-Cr
ru
4=-
County
Coal
field
or
town
Mine
Name
Proximate
analysis , %
g
.a
Date
of
analy-
sis
§
.P
m
.H
Seam S.
I Volatile
S
O
1
E
.c
tn
<
Sulfur
Ultimate
analysis, %
| 1 £ & as
x u z o received
Ash
softening Free
Btu tenpera- swelling
dry ture,F° index
Hardgrove
grlndablllty
index
COLORADO (continued)
Weld
n
it
Weld
Houtt
n
n
Houtt
Erie
n
n
n
Fredrick
Oak Creek
M
n
ti
"
ti
n
"
"
ft
n
n
Routt
ft
tt
tl
tf
ff
n
WashlJTg-
ton
tt
n
tt
ti
Graden
Edna
tt
n
n
n
tt
tt
n
11
tt
Johnie's
Pinnacle
Keystone
tt
II
tl
n
n
tt
1918
1950
1948
1919
1950
1918
1917
1950
1950
1917
1917
1919
1950
1950
1950
1917
1917
1918
1918
1918
1918
1918
1918
1918
1950
18.5
15-5
20.7
20.0
20.1
20.0
Lennox 9.9
8.7
7.5
Lennox 9.1
Lennox 10-7
8.1
7.8
9.0
8.9
Lennox 9.9
8.4
8.6
Pinnacle 6.9
7.0
7-1
7.9
10.1
9-0
6.3
10.2
39.5
39.5
38.7
38.7
39-3
11.8
11.3
15.1
15.6
15.2
12.9
13-7
Hk. H
11.7
13.4
12.5
11.2
10-7
12.3
12.0
13.2
12.7
11.7
11.8
53.5
51.9
51.1
51.1
55.6
55.2
51.1
51.5
50.6
50.2
51.1
51.0
51.5
50.14
50.6
52.1
53.1
50.0
52.9
51.7
51.6
52.2
52.6
50.2
50.5
6.3
5.6
6.1
6.9
5.7
5.5
1.1
1.2
1.0
1.2
3-7
6.1
1.8
5.2
1.7
1.2
t.l
8.8
6.1
6.0
6.1
1.6
1.7
8.1
7.7
0.1
0.3
0.1
0.5
0.1
0.1
2.5
2.2
2.3
2.2
2.3
2.3
2.1
2.3
2.3
2.2
0.5
0.6
0.6
0.5
0.6
0.6
0.5
0.6
0.6
- 9,980
- 10,660
9,800
- - - - 9,900
- - - - 10,050
9,950
- 11,910
- - - - 12,070
- - - - 12,200
- 12,060
5-1 71.3 1-9 12.1 11,890
- 11,860
- 12,030
- - - - 11,920
12,020
11,990
5.1 76.5 1-7 11.8 12,360
- - - - 11,620
- 12,320
- - - - 12,290
- - - - 12,210
5-3 75.6 1.7 12.2 12,350
- - - - 12,030
- 11,710
- - - - 12,090
12,250
12,620
12,360
12,380
12,620
12,110
13,250
13,220
13,310
13,300
13,310
12,900
13,050
13,100
13,190
13,310
13,190
12,710
13,230
13,210
13,180
13,110
13,120
12,870
12,900
_ _
2,050
2,070
2,020
-
2,000
_ _
2,050
2,080
— —
2,050
1,980
2,000
2,310
2,140
2,550
2,320
2,570
2,120
2,150
2,730
_
-
-
-
_
_
_
_
_
_
_
.
-
-
-
_
_
_
_
_
_
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
ro
VJI
County
Coal
field
or
town
Mine
Proximate
analysis ,
g
*
Date
of
analy-
Narae sis
to
Seam &
r-t
•H
rH
S
o
1
I
Ultimate
analysis, *
«3 £ 1 3
8" as
o received
Ash
softening Free
Btu tenpera- swelling
dry ture,F° index
Hardgrove
grindabilitv
Index
COLORADO (continued)
Weld
n
n
ti
ti
M
tl
TI
Routt
n
it
it
n
ftoutt
n
it
it
n
n
n
it
n
it
it
Dacono
n
n
it
11
n
n
it
n
Me Gregor
MDunt
Harris
n
n
ti
ii
11
ii
n
ti
n
11
Boulder
Valley
No. 3
n
tt
it
it
n
tt
n
n
Black Dan
n
n
n
n
ti
Harris
n
n
it
it
it
ii
it
tt
ti
1948
1948
1948
1948
1949
1950
1948
1948
1950
1947
1947
1947
1948
1949
1947
1950
1950
1950
1949
1948
1948
1949
1950
1948
1949
1950
1948
Larande" 24.9
24.7
24.6
22.5
22.0
25.1
24.7
22.3
23.0
Wadge 12.7
" 12.9
14.5
13.4
" 12.4
18.3
» 8.1
8.5
6.9
8.7
9.8
8.2
8.1
8.1
9.0
" 8.0
" 8.6
8.9
39-3
39.3
39.7
38.8
38.7
38.7
39.1
39.0
39-4
42.4
41.8
42.9
39-3
37.6
37.8
41.5
40.1
40.3
42.1
40.3
39-0
38.3
40.3
38.4
41.9
39.9
38.7
55.9
55.4
53-7
54.2
54.6
55.3
52.2
53.5
54.2
49.6
47-7
48.2
51-7
49.8
51-3
51.6
52.6
52.8
50.0
51-3
52.5
53-9
52.1
54.6
50.3
52.3
53.4
4.8
5.3
7.2
7.0
6.7
6.0
8.7
7.5
6.4
8.0
10.5
8.9
9-0
12.6
10.9
6.9
7-3
6.9
7.9
8.4
8.5
7.8
7.6
7.0
7.8
7-8
7.9
0.3 4.7 72.8 1.6
0.4
0.7 -
0.6 -
0.5
0.4 -
0.8
0.9
0.5 -
0.6 5-0 71.0 1.8
0.5 -
0.6 -
0.7 -
0.5
0.7 -
1.2
0.5
0.5 -
0.5
0.5
0.5
0.5
0.5
0.4
0.5
0.5
0.5
15-8 9,390
9,400
9,270
9,530
9,590
9,300
9,060
9,470
9,490
13.6 10,860
10,470
10,430
10,660
10,180
9,590
11,760
11,630
11,890
11,540
11,430
11,570
11,640
11,680
11,690
11,590
11,540
11,480
12,510
12,480
12,290
12,300
12,300
12,420
12,040
12,190
12,330
12,440
12,020
12,200
12,310
11,620
11,740
12,800
12,710
12,770
12,640
12,670
12,600
12,660
12,710
12,840
12,600
12,630
12,600
2,080
2,210
1,970
1,970
2,000
2,130
1,970
2,040
2,030
2,680
2,730
2,470
2,510
2,530
2,360
-
2,850
2,910
-
-
-
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
CTv
County
Coal
field
or
town
Mine
Name
Proximate
analysis , 3
1
Date
of
analy-
sis
4J
3
Seam i
Volatile
a
0
1
-H
fr
x:
w
<
Ultimate
analysis , %
f- bO
"3 P
1 5
c
c So c
E t & Btu
1 £ & as
o z o received
Ash
softening Free
Btu tempera- swelling
dry ture.F0 index
Hardgrove
grindabilltv
index
COD3RADO (continued)
Foutt
Moffat
It
II
11
II
Hoffat
11
11
tt
Moffat
tt
Rio
Blanco
it
it
Routt
It
"
11
n
n
Mount
Harris
Axial
n
it
ti
it
Craig
M
tt
tt
Silt
tt
Craig
«
tt
Haybro
tt
tt
11
tt
tt
" Harris
Red Wing
tt
II
11
n
Knez
11
11
n
Harvey
GdD
n
Blue
Streak
ti
11
Hayden
No. 4
"
n
1!
II
"
19W
1950
1919
19148
1918
1919
19H7
1W
1917
1917
1948
1950
19*t7
1947
1947
1918
1918
1918
1919
1918
1918
' Wadge T0.6
Collem 9.3
" 9.2
« 8.5
" 11.1
i. 10.7
15.1
11.2
13.8
13.7
1-3
2.9
11.6
11.2
11.7
7-8
7.1
7-3
6.7
7.1
8.2
39.6
15.3
13.6
10. 1
39.3
39.3
39.2
38.3
39.0
37.1
39.1
38.8
to. it
10.6
10.1
12.6
11.8
11.6
40.6
39.8
10.9
52.8
51.2
53.2
56.3
55.7
51.6
51.9
55.6
53-6
53.2
50.0
19.1
52.7
52.4
53.0
52.6
50.6
17.7
49.0
17.8
19.1
6.7
3.5
3.2
3-6
5.0
6.1
5-9
6.1
7-1
9.1
10.6
11.8
6.9
7.0
6.6
4.8
7-6
10.7
10.4
12.1
9-7
0.5 ' -
0.2
0.1
0.3
0.1
0.5
0.1 5-0
0.3
0.3
0.4
2.0
2.1
0.7
0.6
0.8 5.1
1.1
1.1
1.5
1-3
1.2
1.4
- - - 11,420
12,030
11,960
12,120
11,440
- - - 11,400
72.8 1.7 11.2 10,660
- - - 10,760
- - - 10,670
10,390
- - - 12,220
12,210
11,320
11,110
78.3 1.3 12.9 11,330
12,330
12,330
11,610
- - - 11,690
- 11,360
11,590
12,770
13,270
13,170
13,250
12,910
12,770
12,560
12,530
12,380
12,030
12,770
12,570
12,810
12,810
12,830
13,370
13,030
12,520
12,530
12,270
12,630
_ ^
_ _
_ _
-
-
2,520
2,380
2,380
2,400
2,560
2,180
2,170
2,910*
2,910+
2,840
2,260
2,260
2,360
2,300
2,380
2,310
_
_
_
_
-
_
_
-
-
-
_
_
_
_
_
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
County
Coal
field
or
town
Mine
Proximate
analysis » *
I
Date
of
analy-
Name sis Seam
Moisture
Volatile
a
0
%
X .C
i-4 Vj
fc «
1
Ultimate
analysis , t
o tu
III
* 8 2
I Btu
x as
o received
Ash
softening JVee
Btu tempera- swelling
dry ture.F0 index
Harderove
grindability
index
CODORADO (continued)
Mesa
«
n
it
n
n
IT
II
II
II
ft
*'
II
Tl
II
IT
tl
Los
Animas
n
n
Tl
Mesa
II
II
Tl
Palisade
II
IT
Tl
II
IT
II
n
n
M
Trinidad
11
n
IT
Cameo
n
IT
It
Mount
Garfield
It
TT
"
11
Pasisade
Tt
It
II
Riverside
n
Tl
n
Winger
TT
IT
II
Vallerso
It
It
TT
Cameo
ti
Tl
River
View
1917
191?
1917
1947
19*7
19*7
1917
19*7
19*7
19*7
19*7
19*7
19*7
19*7
19*7
1950
19*7
19*8
19*9
19*8
19*8
19*7
19*7
19*7
Palisade
"
IT
M
n
n
tt
n
n
n
it
It
It
Cameo
n
n
it
Bear
Cannon
No. 6
it
tt
n
Cameo
n
n
it
10.*
10.0
9-9
10.1
9.2
8.3
7.8
8.5
7.*
7-1
6.3
6.5
6.*
7.8
7-1
7.2
7.8
1.8
1.9
1.5
1.8
7.*
6.9
7.*
8.0
11.2
*1.5
*0.2
39-5
37.8
11.3
*0.6
10.1
38.3
39.6
39.5
38.9
38.6
38.*
37.6
39.8
38.7
36.8
35-*
35.0
3*. 7
39.8
38.7
38.8
38.7
53.5 5.3
52.5 6.0
51.6 8.2
51.0 9.5
48.1 l*.l
51.9 6.8
19.7 9-7
147.* 12.5
46.2 15.5
50.8 9-6
47.5 13-0
*8.0 13.1
*7-5 13.9
*7.8 13.8
*8.1 1*.3
*9.2 11.0
*7.8 13-5
5*. 7 8.5
54.1) 10.2
55-1 9.9
53-9 n.*
52.2 8.0
*9.6 11.7
1(9.6 11.6
51.9 9.*
0.8
0.8
0.8
0.9
1.0
0.8
1.1
1.1
1.1
1.0
1.*
1.6
1.1
0.7
0.7
0.8
0.9
0.5
0.6
0.6
0.5
0.6
0.7
0.7
0.7
5-3 75-3 2.0
_ _ _
_ _
_ _
_ -
5.3 75.0 1.9
_ _
_
_ _
5.1 72.5 1.9
_ -
_ -
_ _
_ -
_
1.9 68.8 1.5
_ -
_ _
_ -
_
4.8 7*. 9 1-5
_ -
_ _
5.0 72.9 1.6
11.3 12,050
12,030
11,700
11,1*0
10,780
10.2 12,220
11,920
11,450
11,1*0
9.9 12,0*0
11,640
11,580
11,390
11,260
11,280
11,790
10.* 11,2*0
13,440
13,190
13,360
13,030
10.2 12,110
11,720
11,640
10.4 11,900
13,440
13,370
12,980
12,720
11,880
13,320
12,930
12,510
12,020
12,960
12,430
12,390
12,170
12,210
12,140
12,710
12,190
13,680
13,*50
13,560
13,270
13,070
12,590
12,570
12,930
2,330
2,590
2,750
2,730
2,620
2,470
2,510
2,390
2,310
2,590
2,470
2,220
2,380
2,910+
2,910+
-
2,860
-
-
-
- ' -
2,5*0
2,860
2,800
2,700
_
_
-
-
-
-
-
-
-
_
-
-
-
-
-
-
-
-
-
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
no
co
County
Mine
Proxiirate
analysis , %
&
Coal Date
field of
or analy-
town Mane sls Seam
Moisture
Volatile
3
O
TJ
8 ^
E 3
Ultimate
analysis, %
G
m S
c
1 Btu
x as
o received
Ash
softening Free
Btu tenpera- swelling
dry ture ,P° index
Hardgrove
grlndability
index
COLORADO (continued)
Mesa
It
tr
n
n
Mesa
n
"
Las
Anlnas
n
ii
it
"
"
las
ArJras
"
"
n
Fruita Hidden
Treasure
" Hy-Grade
" "
11 n
it n
Grand Monarch
Junction
IF T!
" "
Rugby Kenneth
M U
n n
11
"
"
Rapson
"
11
"
ii
" "
Rugby Kenneth
i' n
it 11
n n
1947 Palisade
1917 "
1947 "
1917 "
1947 "
1917 "
1947 "
1947 "
1917
1919
1917
1948
1917
1947
1917
1949
1917
1950
1950
1947
1947
19^5
1947
1948
8.3
9-2
8.5
8.5
8-5
9.1
9-8
8.1
2.2
1.8
2.2
2.1
2.3
2.9
2.3
2.2
2.1
2.4
2.2
2.9
2.2
1.3
2.2
2.1
39.1
39.1
39.5
38.8
36.5
41.4
39.0
35.7
35.6
35.5
36.8
36.2
35.8
34.6
37.2
37.5
36.9
31.6
35.3
35.5
35.6
35.5
36.8
36.2
51.7 5.9
53.1 7.2
52.0 8.5
19.8 11.4
47.8 15.7
19.4 9.2
17.1 13.6
39.0 25-3
51.6 12.8
50.8 13-7
50.8 12.4
50-5 13-3
18.0 16.2
15.3 20.1
50.0 12.8
51.8 10.7
19.8 13-3
18.5 16.9
18.1 16.3
47-8 16.7
51.6 12.8
5C.3 13.7
50.8 12.1,
50.5 13.3
0.7 5-3
0.6 5-1
0.6
0.6
0.8
0.6 5.2
0.7
1.0
0.6
0.6
0.5 5.0
0.5
0.5 -
0.7
0.6 5-0
0.6 -
0.7
0.6
0.5
0.7
0.6
pi ,-;
0~5 5.0
0.5 -
76.2 1.8
75.1 1.8-
-
-
-
72.8 1.7
_
-
_
_
72.9 1-2
-
-
72.2 1.3
_
-
- -
-
-
_
-
72.9 1-2
-
10.1 12,430
10.2 12,100
12,030
- 11,720
10,950
10.5 11,700
11,060
9,170
12,110
12,430
8.0 12,550
12,500
11,970
11,310
8.1 12,610
12,950
12,480
11,920
12,070
11,910
12,440
12,430
3.0 12,550
12,500
13,560
13,320
13,150
12,820
11,960
12,920
12,250
10,310
12,730
12,650
12,840
12,770
12,260
11,650
12,910
13,240
12,790
12,210
12,340
12,270
12,730
12.65C
12,840
12,770
2,680
2,570
2,620
2,650
2,510
2,590
2,750
2,630
2,910+
_
2,890
2,840
2,680
2,910+
_
2,910+
-
2,910+
2,910+
2,910+
-
2,590
-
_
_
_
-
-
_
_
-
_
_
-
-
-
-
-
-
-
-
-
-
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
ro
vo
Proximate
analysis, *
County
Coal
field
or
town
Mine
Name
Date
of
analy-
sis seam
W
.H
(— t
«
1
•i
a
o
1
E
sz
COLORADO
Las
Animas
ii
n
ii
n
n
Las
Animas
Tl
Las
Animas
n
n
La Plata
II
II
II
II
Rugby
M
"
„
Stark-
viUe
ii
Trinidad
It
II
II
II
II
Hesperus
fi
ii
ii
n
Kenneth
Rapson
n
11
n
ii
n
Stark-
vllle
No. 4
II
Baldy
No. 2
Peacock
R. and G.
II
Mlnoletti
„
"
1947
1947
1947
1949
1947
1950
1950
1947
1947
1947
1947
1947
1947
1947
1947 No. 4
1947 "
1948 Hesperus
1948 "
1948 "
1948 "
1949 "
2.3
2.9
2.3
2.2
2.4
2.4
2.2
2.9
1.4
1.2
1.7
1.6
1.6
1.3
1.4
2.1
4.5
3.8
3.7
3.6
3.3
35.8
34.6
37.2
37-5
36.9
34.6
35.3
35.5
30.9
31.4
32.2
32.5
35.2
35-6
28.3
30.6
41.0
41.0
41.0
40.4
39-7
48.0
45.3
50.0
51.8
49.8
48.5
48.4
47.8
52.6
52.3
53-3
48.3
52.6
49.0
49.1
50.3
54.6
52.8
51.7
50.7
51.1
16.2
20.1
12.8
10.7
13.3
16.9
16.3
16.7
16.5
16.3
14.5
19.2
12.2
15.4
22.6
19.1
4.4
6.2
7.3
8.9
9.2
Ultimate
analysis , *
1 |
(continued)
0.5
0.7
0.6 5.0
0.6
0.7
0.6
0.5
0.7
0.7
0.7 4.8
0.6 4.8
0.6
0.6 5-1
0.6
0.5
0.6 4.7
1.4 5-4
2.2
2.6
2.3
2.4
c 8:
-
72.2 1.3
— —
_
-
71.8 1.3
72.1 1.2
73-8 1.5
69.0 1.2
78.1 1.8
_ __
-
| Btu
x as
o received
11,970
11,310
8.1 12,610
12,950
12,480
11,920
12,070
11,910
12,570
5.1 12,650
6.8 12,630
11,930
6.8 12,900
12,400
11,550
5.4 12,080
8.9 13,460
13,260
13,050
12,800
12,830
Btu
dry
12,260
11,650
12,910
13,240
12,790
12,210
12,340
12,270
12,750
12,800
12,840
12,120
13,100
12,560
11,700
12,340
14,090
13,780
13,550
13,280
13,270
Ash
iofterJng Free Hardgrove
tempera- swelling grindablllty
ture ,P° Index Index
2,840
2,680
2,910+
2,910+
2,910+
2,910+
2,910+
2,910+
2,880
2,870
2,420
2,870
2,910+
2,910+
2,210
2,100
2,200
~
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
UJ
o
County
Coal
field
or
town
Mine
Narre
Proximate
analysis, <
1
tote |
of 5
analy- -3
sis Seam £
Volatile
a
o
I
E
1
Sulfur
Ultimate
analysis, %
flJ V
•9 t *:
$ 8 S
| Bta
x as
o received
Ash
softening Free
3tu tenpera- swelling
dry ture ,F° index
HardBTOve
griniibilit.v
index
OOUDRADO (continued)
Las
Anlnas
n
n
Jackson
la Plata
Hesperus
n
n
Boncartx>
"
Delagua
Ludlow
Coalmont
Eurango
w
**
"
ft
**
Hesperus
VrisJit
n
n
Anchor
n
Delagua
Uiilow
Moore
Strip No
Peerless
«
Victoiy
tt
R
ft
Coal
Kli« tto.l
19118
1948
1948
1947
19*17
19*7
1947
19*8
19*7
19*8
1950
19*7
19*7
. 2
19*8
19*8
1948
1948
19*6
1948
1948
Hespetvs 3.7
3.3
" 3.*
Prtnero 1.8
1.4
Cass 2.6
No 2. & 3 1.5
1.7
1.8
1.4
1.4
2.2
1.8
Rlaach 20.8
2.8
2.7
2.5
2.1
2.6
2.9
Hesperus 4.1
140.8
U0.6
42.1
33-9
34.2
36.0
35.1
35.4
34.0
33.9
31.5
32.7
33.6
43-*
39-9
38.1
39-3
38.9
38.3
39.9
42.3
51.3
19.6
50.1
55.9
48.5
46.9
46. 3
51.1
*8.8
48.8
50.1
*5.5
*9-0
50.6
55-9
52.9
55-3
54.4
54.0
52.2
53-7
7-9
9.8
7.8
10.2
17-3
17.1
16.6
13-5
17-2
17.3
18.4
21.8
17.4
6.0
4.2
9.0
5-4
6.7
7.7
7.9
4.0
2.4
3.6
2.6
0.6
0.6
0.7
0.6
0.7
0.5
0.8
0.6
0.7
0.7
0.5
0.8
0-7
1.7
1.6
1.6
1-3
0.8
5.4 75-1 1.7
4.3 76.1 1.5
-
5.0 6S.5 1.4
4.9 70.0 1.2
- . _
_
- — _
_
_ _
- - -
5-0 69.8 1.5
5.4 80.0 1.6
_ _ _
5.4 79-4 1.5
_ _ _
_ _ _
— .. _
5-6 79-0 1.8
13,050
12,810
7.4 13,150
6.8 13,120
12,200
7.3 11,930
6.7 12,360
12.770
- 12,230
12,280
12,110
11,430
12,160
17-2 9,620
8.0 14,010
13,260
6.6 13,950
13,790
- 13,600
13,510
8.8 13,640
13,560
13,250
13,610
13,360
12,380
12,240
12,550
12,990
12,450
12,450
12,280
11,660
12,330
12,150
14,410
13,650
14.320
14,140
13,970
13,920
14,230
2,470
2,230
2,230
2,250
2,680
2,680
2,910+
2,910*
_ _
2,910*
2,910+
2,690
2.230
2,850
2,910*
2,030
2,390
2,600
2,670
2,820
-
-
-
-
_
_
_
_
_
_
-
_
_
—
_
—
—
1943
1.1 40.0 50.8 9.2 1.1
12,860 13,410 3,520
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
Mine
County
Coal
field
or
town Name
Date
of
analy-
sis seam
1
-P
VI
Proximate
analysis , •*
c
&
Volatile
%
c
TJ
E
I
Ultimate
-lei
e £ B £
3 >> 5 ~H
OT 5? U Z
p, Etu
f? as
c received
c
Btu
dry
Ash
oftenirjj I-Y-ee
tenpera- swelling
ture,F° index
Hardk^ove
grirdability
index
COLORADO (continued)
La Plata
"
"
"
11
it
Gunnison
n
11
n
Huerfans
"
u
u
u
n
it
n
u
ti
n
"
"
Hesperus Coal
King No.
n 11
ii tt
Gay
Gulch No
n ti
ti ti
Somerset Somerset
u n
ti n
tt tt
Walsenburg Loma
Park
" Homing
Glory
it n
ii tt
ii n
ii »
11 tl
II 11
" Raven-
wood
n n
n 11
it it
M n
1948 Hesperus
2
1948 "
1948 "
1948 "
.2
1948 "
1948 "
1947 B
1947 B
1947 B
1948 B and C
1949 Walsen
1947 Upper
Robinson
1947
1948
1950
1949
1950
1947
1949 Cameron
1949 "
1950 "
1949 "
1950 "
4.1
3.8
3-8
5-2
5-2
5-1
6.0
5.4
5-5
5.6
5.9
6.3
4.4
4.5
3.8
5-9
3-6
3-1
5.5
3-3
3-3
41.0
40.4
39.4
40.5
39-0
38.2
39.6
38.3
35.2
41.3
39.1
37.3
38.2
38.1
38.7
39-1
38.4
39-0
39.9
38.9
37.9
54-3
51.9
51-7
53-9
52.2
51.6
51.5
43.1
47.0
50.0
50.2
54.2
52.1
50.2
51.0
46.2
51.6
51-7
50.7
51.3
50.4
4.7
7.7
8.9
5.6
8.8
10.2
8.9
13.6
17.8
8.7
10.4
8.5
9-7
11.7
10.3
14.7
10.0
9.3
9-4
9.8
11.7
0.7 5.5 78.3 1.7
0.8
1.2 -
1.1 5.3 77.2 1.7
0.6 5-2 74.2 1.5
0.5
0.5
0.5
1.3
0.6 4.9 72.5 1.2
0.5
0.5
0.6
0.6
0.6
0.5
0.6
0.6
0.6
0.7 - -
0.6
9-1 13,520
13,110
12,950
9.1 13,210
9-7 12,560
12,340
12,410
11,610
10,060
12.1 12,000
11,770
12,050
12,100
11,880
12,100
11,130
12,480
12,720
12,040
12,610
12,310
14,090
13,630
13,460
13,930
13,250
13,010
13,270
12,270
10,650
12,710
12,500
12,860
12,660
12,440
12,580
11,830
12,950
13,120
12,730
13,040
12,730
2,910+
2,910+
2,690
2,500
2,440
2,520
2,570
2,280
2,490
2,500
2,470
-
-
-
-
2,450
2,870
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
~
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
-fr
oo
rv>
County
El Paso
n
Fremont
It
tf
II
11
Delta
n
ft
M
Elbert
Mine
Coal
field
or
town Nane
Proximate
analysis . *
g
Date t
of I
analy- 2
sls Sean £
Colorado PUce View igliS
Springs
tl
w
n
n
ti
ft
Florence B 4 B
" Corley
No. 6
•* «
" Pine
Gulch
" n
" Vento
n ft
n it
Paonla Delta W
n it
" it
" Paonla
Fanners
Matheson White Ash
1919
1918
1918
1919
1918
1918
1918
1917
1918
1919
1950
1950
1950
1950
1950
1917
1917
1917
1917
1917
1918
Pox Hill 214.1
21.2
25.1
18.2
25.1
21.9
22.1
21.2
Lower 9.9
Jack
O1 lantern
8.5
7.1
7.6
7.9
9.6
8.8
8.9
10.6
10.7
11.6
9.2
9.2
32.9
«
.P
c<
3
13.0
12.3
12.6
13.3
13.0
12.9
13.2
10.9
37.0
39.9
10.6
39.7
10. 0
38.8
37.1
37.7
38.0
37.7
36.6
12.3
"42.0
12.2
1
O
1
E
1
i.
a
Jit taste
vialyrl? . *
| | I | Btu
& ? £ i? ac
S 8 Z & received
OODORADO (continued)
19.1 7.6-0.1 .... 8>62Q
50
50.1
19.3
19.9
19.1
19.5
18.9
18.6
19.1
17.9
52.1
51.9
52.6
51.6
50.7
19-1
18.1
19.7
51.5
51.3
15-3
7.7
7.0
7.1
7.1
8.0
7.3
10.2
11.1
10.7
11.5
7.9
8.1
8.6
11.3
11.6
12.9
13.9
13-7
3.2
3-8
12.0
0.1
0.1
0.1
0.1
0.1
0.1
0.5
1.1
0.1
0.5
0.9
0.8
0.5
0.5
0.5
0.7
0.7
0.8
0.6
0.6
0.7
1.5 67.6 0?8 19.7 81650
~ - - - 9,310
- - - - 8,600
8,570
- 8,800
- - - - 8,160
1.7 66.1 1.1 12.3 10,1^0
10,820
- - - - 10,810
- - - - 11,640
- - - - 11,500
- 11,180
- - - 10,890
- 10,81)0
1.7 67.5 1.6 12.6 10,610
- - - 10,190
10.100
5.1 77.5 1.8 11.5 12,190
12,380
1.5 61. P !.3 16.7 7,313
Ash
softening Free
5tu tenpera- swelling
dry tur>e,F° Index
11,360
11,310
11,510
11,380
11,190
11,110
11,300
11,170
11,600
11,820
11,670
12,600
12,490
12,370
11,910
11,900
11.870
11,710
11,830
13,750
13,610
9,130
2,310
2,360
2,130
2,260
2,100
?,720
-
2,230
2,310 -
2,290
2,910+
2.910+
2,910+
2,700
2,760
2,280
Hairlnxive
grlirJatlllt
InJex
_
-
-
_
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
uo
oo
Mine
County
Coal
field
or
town
Mane
Date
of
analy-
sis Seam
%
-g
•H
£
Proximate
analysis ,
c
?c?
12^140
12,210
2,170
2,210
2,200
2,180
2,160
2,210
2,240
2,360
2,290
2,240 - 27.7
2,620
2,690
28.1
2,630 26.9
-
2,030
2,050
2,000
2.C30
2,050
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
-Cr
00
County
Mine
Coal
field
or
town Name
Proximate
analysis , %
I
Date
of
analy-
sis Seam
1
1
I
i— t
«H
1
i
^
s
fi
c.
co
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
Coal
field
or
Count v town
Mine
Date
of
analy-
!!a~K sis Sear,
£
Proximate
analysis , *
g
dj ra
r-l 0 .
*"* ~* -<
r^ g — ~^
> E •* —
| £
of
c
& c
? £
3 o
Btu
received
Ash
33ftenir.g Free
Iry T.;re,r= Index
Hardgrove
lr.de x
COLORADO (continued)
Gunnison Somerset
ii
Gar-field Glenwood
Springs
Gunnison Baldwin
ti "
ii ii
ii 'i
Oliver
No. 2
IT
11
M
II
(I
South
Canon
No.l
H
n
Sunlight
n
Baldwin
Star
Kubler
New
Baldwin
Nu-Mine
"
1947 D
1949
1947 D
1948
1949
1947 D
1947 D
1947 '
1947 '
1947 '
1950 '
1947 '
1947
1947
1947
1947
1947
1947 No.l
1947 "
1947 "
5.8
5.9
5.8
5-7
5-5
5-2
6.7
6.6
6.4
5-5
5-2
7-5
12.7
12.3
9-0
8.5
9.0
10.7
10.3
10.0
40.9
40.4
40.1
38.9
39-8
39.0
42.8
42.7
'42.7
42.8
39-9
42.2
41.7
42.4
38.7
38.3
33.5
41.6
41.8
40.9
53-7
52.6
52.6
50.7
50-5
52.2
54-9
53.8
53.7
53.7
49.6
53.7
52.6
50.9
55.4
55-7
52.4
50.6
53-1
53.4
5-4
7.0
7.3
10.4
9-7
8.8
2.3
3.5
3.6
3.5
10.5
it.l
5.7
6.7
5.9
6.0
9.1
7.8
5.1
5.7
0.5
0.5
0.4
0.6
0.6
0.6
0.5
0.6
0.6
.7
1.5
0.8
0.9
1.3
0.5
0.4
0.4
0.6
0.6
5-2 "77.2
5.2 74.2
5.4 76.9
5.5 76.8
5.3 72.9
5.2 75.2
5.4 74.1
1.6 10.1
1.5 9.7
2.0 12.9
1.8 11.7
1.6 13.6
1.6 11.6
1.7 13.1
12,800
12,540
12,520
12,090
12,170
12,560
12,780
12,700
12,650
12,980
11,840
12,560
11,360
11.290
12,050
12,140
11,550
11,460
11,390
11 sio
13,560
13,320
13,290
12,820
12,830
13,250
13,690
13,600
13,520
13,730
12,490
13,570
13,010
12,880
13,240
13,270
12,690
12,840
13,260
13 120
2,760
2,910+
2,780
2,440
2,320
2,420
2,470
2,380
2,220
2,710
2,200
2,130
2,330
2,310
2,380
2,290
2,270
-
-
-
-
-
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
oo
County
Coal
field
or
town
Mine
Name
Proximate
analysis , <
I
Date
of
analy-
sis
-p
to
^H
Seam £
Volatile
a
0
•H
fc
r:
to
<
COUORADO
Delta
n
Elbert
El Paso
fl
tt
II
ft
II
II
II
II
II
n
IT
II
II
11
II
ft
Fremont
it
Paonla
Colorado
Springs
n
n
n
n
n
n
tt
Tl
(1
II
n
11
tt
it
ti
ii
Florence
it
Paonla
Fanners
n
White
Ash
City
No.4
n
it
«
n
France-
vllle
»
n
n
Pike
View
t|
II
It
II
tt
tl
tl
B & B
Corly
1917
1947
1918
1917
igi(7
19^7
1947
19117
1917
19H7
19t7
19*17
191(8
19119
1948
19M9
1948
1948
1948
1948
1947
1948
9-2
9.2
32.9
R>x Hill 24.7
" 24.7
" 24.4
" 25.2
" 26.2
" 23.1
" 22.3
" 22.7
" 22.6
" 24.1
" 24.2
" 25.1
" 18.2
" 25.1
" 24.9
" 22.1
" 24.2
Lower Jack 9.9
0' lantern
8.5
42.3
42.0
42.2
44.0
43.2
42.5
44.6
41.1
41.6
40.7
39.8
39-8
43.0
42.3
42.6
43-3
43.0
12.9
43.2
40.9
37-0
39-9
54-5
54.2
45.8
47.6
48.5
45.8
45.0
46.5
49.5
47-3
44.9
45.1
49.4
50.0
50.4
49.3
49-9
49.1
49.5
48.9
48.6
49.4
3-2
3.8
12.0
8.4
8.3
11-7
10.4
12.4
8.9
12.0
15-3
15-1
7.6
7.7
7.0
7.4
7-1
8.0
7.3
10.2
14.4
10.7
1 Sulfur
Ultimate
analysis,
bo c
P ^-
*
-^ >> as
2 o received
Ash
softening Free
Btu tempera- swelling
dry ture ,F° irdex
Hardgrove
grindability
index
(continued)
.6
.6
.7
.5
.4
.4
.5
.4
.4
.4
.4
.4
.4
.4
.4
.4
.4
.4
.4
.5
1.4
.4
5.4 77.5
-
4.5 64.8
-
4.5 67.3
- _
- -
- _
4.8 66.9
- _
- -
-
-
- -
1.5 67.6
-
-
-
-
— -
4.7 66.1
-
1.8 11.5 12,490
12,380
1.3 16.7 7,340
8,660
1.0 18.5 8,570
8,270
8,360
8,090
1.2 17.8 9,040
8,830
8,410
8,370
8,620
8,570
.8 19.7 8,650
9,310
8,600
8,570
8,800
8,460
1.1 12.3 10,450
10,820
13,450
13,640
9,430
11,500
11,380
20,930
11,180
10,980
11,750
11,360
10,880
10,820
11,360
11,310
11,540
11,380
11,490
11,410
11,300
11,170
11,600
11,820
2,700
2,760
2,280
2,170
2,210
2,200
2,180
2,160
2,210
2,240
2,360
2,290
- -
-
2,310
- -
2,360
2,130
2,260
2,100
2,720
- -
-
—
-
-
-
-
-
-
—
-
—
—
—
-
-
-
~
-
—
"
-
~
No.6
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
-Cr
CO
O3
Coal
field
or
County town
Fremont Florence
n n
n n
n n
n n
•** n
Garfleld Glenwood
Springs
Gurmison Baldwin
n
"
Mine
Proximate
analysis , *
1
Date
of
analy-
Name sis Seam
Corly
No. 6
KLne
Gulch
it
Vento
n
it
South
Canon No
n
n
Sunlight
n
n
Baldwin
Star
n
Kubler
1949"
1950
1950
1950
1950
1950
1947 D
.1
1947
1947
1947
1950
1947
1947
1947
1947
1 !
~ f.4 «0.6
7-6 39-7
7-9 40.0
9.6 38.8
8.8 31.1
8.9 37.7
6.7 42.8
6.6 42-7
6.9 42.7
5-5 42.8
5-2 39-9
7-5 42.2
12.7 41.7
12.3 42.4
9.0 38.7
1
i
s
1
Sulfur
Ultimate
analysis, %
\ I I
1
COD3RADQ (continued)
47 ."9 ii:r~.5~~" - - -" v
52.4 7.9 .9 - -
51.9 8.1 .8 -
52.6 8.6 .5 - -
51.6 11.3 .5
50.7
54.9
53-8
53.7
53.7
49.6
53.7
52.6
50.9
55.4
11.6
2.3
3-5
3.6
3-5
10.5
4.1
5-7
6.7
5-9
.5
.5
.6
..6
.7
1.5
.8
0.9
1.3
.5
(New Baldwin)
"
n
n
NuMlne
n
n
Bear
w
"
n
n
1947
1947
1947 No.l
1947 "
1947 "
1947 C
1948 "
1949 "
1947 "
1948 "
8.5 38.3
9.0 38.5
10.7 41.6
10.3 41.8
10.0 40.9
5-4 41.1
5-3 40.9
4.5 41.9
5.4 41.3
5.2 40.0
55.7
52.4
50.6
53.1
53.4
53-4
53.8
5*.9
52-9
52.9
6.0
9-1
7.8
5.1
5-7
5.5
5.3
3-2
5.8
7.1
.4
.4
.6
.6
.8
.5
.5
.it
.5
.5
- -
5.4 76.9 2.0
- _ _
- _ _
5.5 76-8 1.8
_ _
- -
5-3 72.9 1.6
— _ _
5-2 75-2 1.6
_ _
_ _ _
_
- -
_ _ _
5-5 76.3 1.7
_ _ _
_ _
-
-
12.9
_
_
11.7
_
-
13.6
_
11.6
_
_
_
_
_
10.5
.
_
-
Btu
as
received
10~,8iO
11,640
11,500
11,180
10,890
10,840
12,780
12,700
12,650
12,980
11,840
12,560
11,360
11,290
12,050
12,140
11,550
11,460
11,890
11,810
12,840
12,980
13,380
12,900
12,760
Ash
softening Free
Btu tempera- swelling
dry ture.F0 Index
11,670
12,600
12,490
12,370
11,940
11,900
13,690
13,600
13,520
13,730
12,490
13,570
13,010
12,880
13,240
13,270
12,690
12,840
13,260
13,120
13,600
13,700
14,000
13,630
13,460
2,230
2,310
2,290
2,320
2,420
2,470
2,380
2,220
2,710
2,200
2,130
2,330
2,310
2,380
2,290
2,270
2,190
2,630
_
2,720
2,650
Hardgrove
grlndabUity
Index
-
-
_
_
_
_
-
_
_
_
—
_
_
„
_
_
-
-
_
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
oo
County
Mine
Coal Date
field of
or analy-
town Name sis Seam
Moisture
Proximate
analysis , "!
g
S <
COLORADO
Gurmison
n
tt
tt
n
n
tt
tt
n
tt
ii
n
n
it
tt
Jackson
Huerfano
n
tt
i,
„
tt
tt
n
Baldwin Bear
tt ti
" Edward's
It It
" Hawk's
Nest
" Oliver's
No. 2
n
n
n
n
Somerset Somerset
n
"
Coalncnt Moore
Strip No
Walsenburg Loma
Park
" Morning
Glory
n ti
n *i
n «
ii ii
ii n
1947
1948
1948
1948
1948
1947
1949
1947
1948
1949
1947
1947
1947
1947
1948
1947
.2
1949
1947
1947
1948
1950
1949
1950
1947
C
tt
B
n
D
D
D
B
B & C
Riaach
Walsen
Upper
Robblnson
n
n
n
n
n
n
5.8
5-3
4.8
5-0
5.3
5.8
5-9
5-8
5-7
5-5
6.5
5.2
5.1
6.0
5.4
20.8
5-5
5.6
5-9
6.3
4.4
4.5
3.8
5-9
41.1
40.5
40.9
40.0
40.6
40.9
40.4
40.1
38.9
39.8
40.4
39-0
38.2
39.6
38.3
43.4
35.2
41.3
39.4
37-3
38.2
38.1
38.7
39.1
53-2
52.9
49.2
50.9
53.9
53-7
52.6
52.6
50.7
50.5
52.0
52.2
51.6
51-5
48.1
50.6
47.0
50.0
50.2
54.2
52.1
50.2
51.0
46.2
5.7
6.6
9-9
9-1
5.5
5.4
7-0
7.3
10.4
9-7
7.6
8.8
10.2
8.9
13.6
6.0
17.8
8.7
10.4
8.5
9.7
11.7
10.3
14.7
Ultimate
analysis, %
£4 60 € M
3 p O p
"""* & *^
(continued)
.5 - - -
.5
.4 - -
.4 - -
.5 - -
.5 5.2 77.2 1.6
.5 - -
.4 - -
.6 - -
.6 - -
.5 - -
.6 5.2 74.2 1.5
.5 - -
.5 - -
.5 - -
.5 5-0 69.8 1.5
1.3 - -
.6 4.9 72.5 1.2
.5 - -
.5 - -
.6 - -
.6 - -
.6 - -
.5 - -
gj Btu
x as
o received
" - "i2,8"io
12,800
12,300
12,480
12,910
10.1 12,800
12,540
12,520
12,090
12,170
12,390
9.7 12,560
12,340
12,410
11,610
17.2 9,620
10,060
12.1 12,000
11,770
12,050
12,100
11,880
12,100
11,130
Ash
softening Free
Btu tempera- swelling
dry ture,F° index
13,600
13,520
12,920
13,140
13,630
13,580
13,320
13,290
12,820
13,250
13,250
13,250
13,010
13,200
12,270
12,150
10,650
12,710
12,500
12,860
12,660
12,440
12,580
11,830
2,610
2,570
- -
2,400
2,400
2,460
_
2,910
— —
- -
2,780
2,440
2,520
2,570
2,280
2,230
2,490
2,500
2,470
- -
— —
- -
- -
2,450
Hardgrove
grindability
index
-
—
-
-
—
-
-
—
—
-
-
-
—
—
~
-
-
—
-
—
*~
"~
~
"
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
jr
-tr
O
Coal
field
or
County town
fttne
Proximate
analysis , ?
g
0
Date
of
analy-
Namg s^ Seam
Buerfano Walsenburg RavaTwood
Tt n n
n n
La Plata Durango
n
"
11
n
ti
La Plata Hesperus
n TT
it n
n it
n
n
"
n
IT
"
n
n
n
n n
w n
n n
n
Peerless
n
Victory
n
n
n
Coal King
No. 1
n
n
Coal King
Ho. 2
n
n
Hay Gulch
No. 2
ffinoletti
n
Wright
No. 2
"
1949 Camsron
1949 "
1950 "
1948
1948
1948
1948 "
1948
1948
1948 Hesperus
1948
1948
1948
1948
1948
1948
1948
1948
1948
1948
1948
1949
1948
1948
1948
I S
to d
O o
£ >
3.6 38.4
3-1 39-0
5.5 39-9
2.8 39-9
2.7 38.1
2.5 39.3
2.4 38.9
2.6 38.3
2-9 39.9
4.1 42.3
4.1 40.0
4.1 41.1
3.8 40.4
3-8 -
5.2 -
6.9 -
8.5 -
4.5 -
3.8 -
3-7 -
3-6 -
3-3 -
3-7 -
3-3 -
3.4 42.1
a
o
V
£
£
s:
1 Sulfur
Ultimate
analysis,
Hydrogen
Carbon
'
to c
COLORADO (continued)
51.6 10.0 .6 -
51.7 9.3 -6 -
50.7
55.9
52.9
55.3
54.4
54.0
52.2
53-7
50.8
54.3
51-9
-
-
—
_
-
-
-
_
_
—
-
50.1
9.4
4.2
9.0
5-1
6.7
7.7
7-9
4.0
9-2
4.7
7-7
8.9
5-6
12.6
16.5
4.4
6.2
7.3
8.9
9.2
7.9
9.8
7-8
.6
.8
.7
1.7
1.6
1.6
1.3
.8
1.1
.7
Q
1.2
1.1
2.0
1.9
1.4
2.2
2.6
2.3
2.4
2.4
3.6
3-6
-
5.4 80.0
_ _
5.4 79-4
_ _
-
5-6 79.0
_ _
5-5 78-3
_
5.3 77-2
_ _
5.4 78.1
- -
_
_
_ _
- -
5.4 75-1
-
1.6 8.0
_ _
1.5 6.6
_ _
_ _
-
1.8 8.8
_ _
1.7 9-1
_
1.7 9.1
_ —
1.8 8.9
_ _
- -
_ _
_ _
- -
_
1.7 7.4
received
12,480
12,720
12,040
14,010
13,280
13,950
13,790
13,600
13,510
13,640
12,860
13,520
13,110
12,950
13,210
11,630
10,860
13,460
13,260
13,050
12,800
12,830
13,050
12,810
13,150
Ash
softening Pree
Btu tempera- swelling
dry ture,P° index
12,950
13,120
12,730
14,410
13,650
14,320
14,140
13,970
13,920
14,230
13,410
14,090
1 "3 fi"^fl
5
13,460
13,930
12,490
11,870
14,090
13,780
13,550
13,280
13,270
13,560
13,250
13,610
2,870
-
2,860
2,910
2,030
2,390
2,600
2,670
2,820
2,520
2,910
'
2,690
2,500
130
2,180
2,210
2,100
2,200
_ _
_ _
2,470
2,230
2,230
Hardgrove
grindability
Index
-
-
_
_
__
—
-
_
_
_
_
_
_
_
_
_
-
_
_
-
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
Coal
field
or
County town
Mine
Proximate
analysis,
!
Date
of
analy-
Naroe sis
m
•H
Seam £
Volatile
S
O
*
£
*
SI
OTSLCRADO
Las
n
n
n
n
n
n
11
n
n
it
n
ti
II
n
ii
n
«
n
n
n
it
n
It
tr
„
11
Antras Boncarbo
IT
Delagua
it
w
n
it
n
n
n
Rugby
u
»
n
Stark-
vllle
Trinidad
n
n
Anchor
n
Delagua
Ludlow
n
n
tr
n
n
ti
Kenneth
n
n
n
n
it
Rapson
"
«
n
M
11
Stark-
ville No
Baldy
No. 2
ir
Peacock
1947
1947
1947
1947
1948
1947
1948
1950
1947
1948
1947
1949
1947
1948
1947
1947
1947
1949
1947
1950
1950
1947
1947
.4
1947
1947
1947
1947
Prlmero i.8~
" 1.4
Cass 2.6
Jtos. 2*3 1.5
" 1.7
1.8
" 1.4
" 1.4
2.2
1.8
2.2
1.8
2.2
2.1
2.3
2.9
2.3
2.2
2.4
2.4
2.2
2.9
1.4
1.2
1.7
1.6
1.6
33-9
34.2
36.0
35.1
35.4
34.0
33-9
31.5
32.7
33.6
35-6
35.5
36.8
36.2
35.8
34.6
37.2
31-5
36.9
34.6
35.3
35.5
30.9
31.4
32.2
32.5
35.2
55-9
48.5
46.9
48.3
51-1
48.3
48.8
50.1
45-5
49.0
51.6
50.6
50.8
50.5
J*8.0
45-3
50.0
51-8
49.8
48.5
48.4
47-8
52.6
52-3
53-3
48.3
52.6
10.2
17-3
17.1
16.6
13-5
17-2
17-3
18.4
2.18
17.4
12.8
13.7
12.4
13.3
16.2
20.1
12.8
10.7
13-3
16.9
16.3
16.7
16.5
16.3
14.5
19-2
12.2
Ultimate
analysis , t
•-H
I
I
g g, Btu
S 5? as
z o received
Ash
softening Free
Btu tenpera- swelling
dry ture,F° index
Harderove
grindabillty
index
(continued)
.6
.6
.7
.6
.7
.6
.8
.6
.7
.7
.6
.6
.5
.5
.5
.7
.6
.6
.7
.6
.5
.7
-7
.7
.6
.6
.6
4.8
-
5.0
4-9
_
—
_
_
-
-
_
5-0
_
_
_
5.0
_
_
_
_
-
-
4.8
4.8
_
5.]
76.1
68.5
70.0
_
_
-
_
_
-
_
—
72.9
_
_
_
72.2
_
-
_
-
-
-
41.8
72.1
_
73.8
1.5 6.8 13,120
12,200
1.4 7-3 11,930
1.2 6.7 12,360
12,770
12,230
12,280
12,110
11,430
12,160
12,440
12,430
1.2 8.0 12,550
12,500
11,970
11,310
1.3 8.1 12,610
12,950
12,480
11,920
12,070
11,910
12,570
1.3 5-1 12,650
1.2 6.8 12,630
11,930
1.5 6.8 12,900
13,360
12,380
12,240
12,550
12,990
12,450
12,450
12,280
11,680
12,380
12,730
12,650
12,840
12,770
12,260
11,650
12,910
13,240
12,790
12,210
12,340
12,270
12,750
12,800
12,840
12,120
13,100
2,250
2,680
2,680
2,910
-
2,910
- -
2,910
2,910
2,890
2,910
- —
2,890
- -
2,840
2,680
2,910
- —
2,910
-
2,910
2,910
2,910
2,910
2,880
2,870
2,<420
-
—
-
—
-
-
-
-
—
-
—
—
-
-
-
—
~
—
-
-
—
-
-
-
-
—
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
County
Coal
field
or
torn
Mine
Proximate
analysis, %
I
Date
of
analy-
Name sis Seam
£
s
1
1
o
-H
1
COICRADO
las Animas
n
n
Las Animas
n
-c^
-f
ro
Mesa
n
n
n
n
n
n
n
n
Tt
tt
n
Trinidad
n
n
Vallerso
n
n
Tt
Cameo
Tt
n
n
Prulta
n
It
it
n
Grand
Junction
n
Palisade
"
Peacock
R & G
n
Bear
Canon No.
n
n
Cameo
n
n
River-
Vlew
Hidden
Treasure
Hy-grade
n
n
n
Monarch
n
Mount
Garfield
n
1947
1947 No. 4
1947 "
1948
6
1949
1948
1948
1947 Cameo
1947 "
1947 "
1947 "
1947 Palisade
1947 "
1947 "
1947 "
1947 "
1947 "
1947 "
1947 "
n
it
tt
1.3
1.4
2.1
1.8
1.9
1-5
1.8
7.4
6.9
7.4
8.0
8.3
9.2
8.5
8.5
8.5
9.4
9.8
8.1
10.4
10.0
9.9
35.6
28.3
30.6
36.8
35.4
35-0
34.7
39.8
38.7
38.8
38.7
39.4
39.4
39-5
38.8
36.5
41.4
39-0
35.7
41.2
41.5
40.2
49.0
49.1
50.3
54.7
54.4
55-1
53.9
52.2
49.6
49.6
51.9
54.7
54.7
52.0
49.8
47.8
49.4
47.4
39.0
53-5
52.5
51.6
15.4
22.6
19.1
8.5
10.2
9.9
11.4
8.0
11.7
11.6
9.4
5.9
7.2
8.5
n.it
15-7
9.2
13-6
25-3
5.3
6.0
8.2
Ultimate
analysis, <
I !
1 I
I Btu
& as
O received
Ash
softening Free
Btu tenpera- swelling
dry ture.F0 index
Hardgrove
grindability
index
(continued)
.6
'.6 4.7
0.5
.6
.6
.5
.6 4.8
.7
.7 -
• 7 5.0
-7 5.3
.6 5.1
.6 -
.6
.8
.6 5.2
.7
1.0
.8 5-3
.8
.8
69.0 1.2
-
: :
74.9 1.5
72.9 1.6
76.2 1.8
75-1 1.8
72.8 1.7
_ _
-
75-3 2.0
- _
-
12,400
11,550
5-4 12,080
13,440
13,190
13,360
13,030
10.2 12,110
11,720
n,64o
10.4 11,900
10.1 12,430
10.2 12,100
12,030
11,720
10,950
10.5 n,70o
11,060
9,440
11.3 12,050
12,030
11,700
12,560
11,700
12,340
13,680
13,450
13,560
13,270
13,070
12,590
12,570
12,930
13,560
13,320
13,150
12,820
11,960
12,920
12,250
10,310
13,440
13,370
12,980
2,870
2,910
2,910
-
-
2,540
2,860
2,800
2,700
2,680
2,570
2,620
2,650
2,510
2,590
2,750
2,630
2,330
2,590
2,750
-
_
-
-
-
™
-
_
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
UJ
County
Coal
field
or
town
Mine
Proximate
analysis, ^
I
Date
of
analy-
NanE sis
Seam
I
£
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
Mine
Coal Date
field of
or analy-
County town Mane sis
Rio Craig Blue 1917
Blanco Streak
n n n igljy
n tt it lgi,7
Houtt Baybro Haden 1918
No. 1
" 1918
1918
" 1919
" 1918
" 1918
Routt McGregor Black Dan
"
"
"
n
"
Ftoutt Mount Harris 1950
Harris
1950
" 1950
n 1949
" 1918
" 1918
n 19J49
" 1950
" 1948
tt igij 9
" " 1919
Proximate
analysis, 1
I
Seam
Wadge
n
n
n
n
n
Wadge
Tt
n
"
n
ii
n
n
it
tt
n
§ a
j-i -p
m a)
S 1
11.6
11.2
11.7
7.8
7.1
7.3
6.7
7.1
8.2
12.1
12.9
11.5
13.1
12.1
18.3
8.1
8.5
6.9
8.7
9.8
8.2
8.1
8.1
9.0
8.0
6.6
10.1
10.6
10.1
12.6
11.8
11.6
10.6
39.8
10-9
12.1
11.8
12.9
39-3
37.6
37-8
11.5
10.1
10.3
12.1
10.3
39.0
38.3
10.3
38.1
11.9
39.9
S
O
!
1
COD3RADO
52.7 6.9
52.1
53-0
52.6
50.6
17.7
19.0
17.8
19-1
19.6
17-7
18.2
51.7
19.8
51-3
51.6
52.6
52.8
50.0
51-3
52.5
53-9
52-1
51.6
50-3
52.3
7.0
6.6
1.8
7-6
10.7
10.1
12.1
9-7
8.0
10.5
8.9
9.0
12.6
10.9
6.9
7.3
6.9
7.9
8.1
8.5
7.8
7.6
7.0
7.8
7.8
Ultimate
analysis, %
H *9 "E 43
(continued)
.7 - -
.6
.8 5.1 78.3 1.3
1.1
1.1 - -
1.5 - -
1.3 - -
1.2
1.1
.6 5.0 71.0 1.8
.5 - -
.6
.7 - -
.5 - -
.7 - -
1.2 - -
.5 - -
.5 - -
.5 - -
.5 - -
.5 - -
.5 - -
• 5 - -
.1
.5 - -
.5 - -
I Btu
i< as
o received
11,320
11,110
12.9 11,330
12,330
12,070
11,610
- 11,690
- 11,360
11,590
13.6 10,860
10,170
10,130
10,660
10,180
9,590
11,760
11,630
11,890
11,510
11,130
- 11,570
11,610
11,680
11,690
11,590
11,510
Ash
softening Free Hardgrove
Btu tempera- swelling grinlabillty
dry ture,F° Index Index
12,810
12,810
12,830
13,370
13,030
12,520
12,530
12,210
12,630
12,110
12,020
12,200
12,310
11,620
11,710
12,800
12,710
12,770
12,610
12,670
12,600
12,660
12,710
12,810
12,600
12,630
2
2
2
2
2
2
2
2
2
2
2
2
2
2
2
,910
290
,810
,260
,260
,350
,300
,330
,310
,680
,730
,170
,510
,530
,360
-
- -
- -
- -
- -
- —
- -
- -
- -
—
,850
_
-
_
-
-
-
-
-
_
-
-
-
-
—
-
-
-
-
-
-
-
-
-
-
~
-------
Table G-l (.continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
Ul
County
Routt
n
Routt
ti
it
n
n
«
n
ti
n
n
w
n
Routt
n
n
n
tt
n
it
Weld
Tt
It
tl
If
tt
Mine
Coal
field
or
town Name
Mount Harris
Harris
H tt
Oak Creek Edna
n n
M «
it
n
tt
ti
tt
tt
11
Johnie's
" Pinnacle
Routt Keystone
it M
n it
n it
it it
n ii
n ti
Daoono Boulder
Proximate
analysis , f>
g
•o
Date
of
analy-
sis seam
1949 Wadge
1950 "
1947 Lennox
1950
1950
1947 Lennox
1947 "
1949
1950
1950
1950
1947 Lennox
1917
1948
1948 Pinnacle
1948
1948
1948
1948
1948
1948
1948 Laramie
Valley No. 3
n n 19i)8 "
" n TQliR "
tt tt
n ti
1948 "
1949 "
1950 "
1948 "
Moisture
8.9
10.6
9.9
8.7
7.5
9-1
10.7
8.1
7.8
9-0
8.9
9.9
8.1
8.6
6.9
7.0
7-1
7.9
10.1
9.0
6.3
24.9
24.7
24.6
22.5
22.0
25-1
24.7
Volatile
38.7
39.6
44.8
44.3
45.4
45.6
45.2
42.9
43.7
44.4
44.7
43.4
42.5
41.2
40.7
42.3
42.0
43.2
42.7
41.7
41.8
39-3
39-3
39.7
38.8
38.7
38.7
39.1
a
O
I
£
1
Sulfur
Ultimate
analysis ,
I 1
tr
M C
£ 8
COLORADO (continued)
53.1 7-9 .5 - - -
52.8 6.7 -5 - -
51.1 4.1 2.5 - -
51.5 1.2 2.2 - - - -
50.6 1.0 2.3 - - - -
50.2
51.1
51.0
51.5
50.4
50.6
52.4
53.1
50.0
52.9
51-7
51.6
52.2
52.6
50.2
50.5
55-9
55.1
53.1
51.2
54.6
55.3
52.2
4.2
3.7
6.1
4.8
5.2-
1.7
1.2
1.1
8.8
6.4
6.0
6.4
4.6
4.4
8.1
7.7
4.8
5-3
7.2
7.0
6.7
6.0
8.7
2.2
2.3
2.3
2.1
2.3
2.3
2.2
.5
.6
0.6
•5
.6
.6
.5
.6
.6
.3
.4
.7
.6
lit
.8
_ _
5-1 74.3
- -
-
- -
- -
—
5-1 76.5
- -
-
-
5-3 75-6
-
-
-
4.7 72.8
-
— -
-
-
1.9 12.1
-
-
-
-
-
1.7 11.8
— -
: :
~
1.7 12.2
-
-
-
1.6 15.8
-
_ _
: :
Btu
as
received
11,480
11,420
11,940
12,070
12,300
12,060
11,890
11,860
12,030
11,920
12,020
11,990
12,360
11,620
12,320
12,290
12,240
12,350
12,030
11,710
12,090
9,390
9,400
9,270
9,530
9,590
9,300
9,060
Ash
softening Free
Btu tenpera- swelling
dry ture ,P° Index
12,600
12,770
13,250
13,220
13,310
13,300
13,310
12,900
13,050
13,100
13,190
13,310
13,490
12, "'10
13,230
13,210
13,180
13,110
13,120
12,870
12,900
12,510
12,480
12,290
12,300
12,300
12,420
12,040
2,910
2,000
2,050
2,080
- -
- -
2,050
1,980
2,000
2,310
2,440
2,550
2,320
2,570
2,420
2,450
2,730
~ ~~
2,080
2,210
1,970
1,970
2,000
2,130
1,970
Hardgrove
grindability
index
-
-
-
-
-
—
—
—
—
~
_
-
—
—
—
~
-
_
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
-tr
-C="
O\
Mine
Proximate
analysis , I
1
Coal Date
field of
or analy-
Gounty town Name sls Seam
Weld Dacono Boulder
41
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
County
Coal
field
or
town
Mine
Proximate
analysis , *
I
Date
of
analy-
Naire sis
Seam
Moisture
Volatile
•8
T4 W
ft. <
COLORADO
Weld
Delta
it
n
n
it
ii
tt
Garfleld
n
tt
n
n
ti
it
Frederick
Grand Mesa
n
11
n
Somerset
ii
Book
Cliffs
n
Carbondale
n
Grand
Ifogback
tt
tt
tt
r*nA0+-£»/4
Graden
Green
Valley
Red Canon
Tomahawk
Top
King
Paonia
Pannes
Carbon-
era
Stove
Canyon
Pocahon-
tas
Sun-
light
Coryell
New
Castle
S. Canon
Vulcan
«1n1no
1948
1959
1955
1959
1959
1966
1954
1926
1954
1906
1955
1909
1959
1959
1911
10-5-5
Green
Valley
Mo. 5
A
No. 5
B
B
Carbon-
era
n
D
D
Allen
n
n
n
20.0
14.0
13-9
13.7
14.5
4.0
8.8
11.4
6.7
6.1
4.4
4.1
3-9
8.2
7.1
11.2
39-3
39.1
38.7
40.5
41.3
41.2
41.7
35-5
40.6
38.5
42.2
38.2
44.5
40.9
40.8
41.4
55-2
54.1
54.4
51.5
53-6
52.5
53.7
43.7
51.7
53.5
54.0
52.7
50.6
55.1
46.9
51.9
5.5
6.8
6.9
8.0
5.1
6.3
4.6
9.1
7.7
1.9
3.8
5-0
4.9
4.0
5-2
6.7
Sulfur
Ultimate
analysis ,
Hydrogen
i
%
Nitrogen
1 Btu
x as
o received
Ash
softening Free
Btu tempera- swelling
dry ture,P° index
Hardgrove
grindability
index
(continued)
.4
0.8
.7
1.0
.6
.6
.6
.6
.7
.5
.9
.5
.6
.4
-5
.9
-
-
5-2
4.9
5-5
-
-
5.6
5-5
5-2
5.5
5.4
5-1
5.6
-
-
75.2
71.2
77.0
-
-
72.2
76.1
73.0
76.9
76.9
70.8
67.6
-
-
1.8
1.6
1.6
-
-
1.7
1.9
1.7
1.8
2.0
1.6
1.2
-
-
13.2
12.8
10.4
-
-
18.1
13.5
14.6
10.3
12.9
16.4
20.0
9,950
11,040
11,100
10,960
11,240
13,190
12,420
11,150
12,380
13,170
13,010
13,230
13,120
12,310
12,620
11,440
12,440
12,830
12,890
12,700
13,140
13,740
13,610
12,570
13,270
14,030
13,600
13,790
13,660
13,420
13,590
12,870
- -
2,330
2,380
2,810
2,570
2,860
2,620
2,850
-
-
2,650
-
2,280
2,280
2,370
2,190
-
59
49
53
56
47
52
-
-
-
48
-
-
-
-
Gunnison Crested
Butte
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
oo
County
Coal
field
or
town
Mine
Proximate
analysis , '
§
Date
of
analy-
Name sis
Seam
4J
^t 1
V
-H
H
-4
Ultimate
analysis , %
TJ J3 Q? §
CJ C L £,
X & rH T3 ti
•H CO 3 >j m
fc -3 « £ 8
CODORADO
Gunnlson
n
it
n
it
ti
ti
ti
Mesa
n
n
n
Maffat
n
Pitldn
n
n
It
Crested
Butte
tl
n
if
Somerset
n
n
n
Book
Cliffs
n
n
Danftirth-
H1U
n
Carbon-
n
tt
n
Bulkley
Crested
Butte
Floresta
Horace
Bear
Hawk's
Nest
Oliver
Somerset
•Book
Cliffs
Cameo
Carfeld
Palisade
Red Wing
Streeter
Coal
Basin
Dutch
Creek
Spring
Thompson
1909
1930
1911
1951
1966
1965
1955
1952
1911
1958
1906
1906
1959
1923
1908
1959
1909
1961
No. 1
Crested
Butte
Ruby
C
E
E
B
Cameo
Palisade
it
Collum
it
Sunshine
B
Anderson
n
' 971
3.2
3.6
3.9
6.9
6.6
6.9
5.7
7-5
8.2
11.0
7.5
11.2
10.6
3.1
1.9
3.1
2.3
33-7
38.7
1.9
6.2
39.6
12.0
10.1
39.5
36.1
39.0
31.3
36.0
13.2
38.5
23.1
23.0
31.0
31-9
52.1
56.1
18.5
83.6
51.5
51.3
51.1
51.6
53.1
50.2
18.7
50.5
53.8
18.1
67.1
68.6
55-1
57.5
1.8
5.2
16.6
10.2
8.9
3.7
5.2
8.9
10.2
10.8
6.0
6.0
3-0
2-5
9-5
8.1
7-2
7.6
i
I Btu
x" a5
o received
Ash
softening Free
Btu tempera- swelling
dry ture,P° index
Hardgrove
grlndability
Index
(continued)
.1
.1
.8
.6
.5
.5
.6
.1
.6
.6
.6
.9
.1
.2
.7
.6
.6
.6
5-5
5.6
3.2
5.5
5-5
5-2
.5-3
5.5
5.5
5.8
5-3
-
5-9
1.7
1.8
5.1
1.9
38.7
71.8
82.3
76.3
79.2
69-9
69.7
61.8
65-5
62.2
68.1
-
66.8
79-6
81.9
71.5
72.8
1.3
1.6
1.3
1.7
1.7
1.1
1.1
1.1
1.2
1.1
1.6
-
1.2
1.8
2.0
1.6
1.9
19.3
12.7
i.6
10.5
9.8
11.1
11.0
21.0
16.5
21.0
17.8
-
23.1
1.8
2.3
10.7
5-1
12,200
13,530
11,830
13,210
12,170
13,060
12,690
12,110
11,780
11,690
10,860
12,310
11,820
11,830
13,980
13,780
13,500
13,900
13,160
13,970
12,270
13,710
13,070
13,990
13,630
13,220
12,710
12,110
12,620
13,310
13,310
13,230
11,130
11,180
13,980
11,230
-
2,250
2,210
2,570
2,110
2,510
2,120
-
2,910
2,130
-
-
2,250
2,120
_
-
27
16
51
50
16
-
50
51
-
-
110
69
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
vo
Coal
field
or
County town
Mine
Date
of
analy-
j&me sis Seam
Proximate
analysis ,
I
Moisture
Volatile
a
o
1
.H
Pi
t
1
COLORADO
Rio - Danforth-
Blanco Hill
n n
" Lower-
White
River
Gunnison Coal
Creek
n n
n n
It n
n n
it Paonla
Coalfield
„
tt
n
tt
ii
„
it
Blue 1955
Streak
Rienay 1958 Rienay
White- 1965 "
River
Coredrill
n
n
Oliver No. 10
No. 10
Hawk's No. 13
Nest
Coredrill
n
n
n
it
n
n
H
11 Unknown
« it
12.9
13.8
11.2
2.4
2.4
2.1
4.1
5-7
10.2
10.8
10.3
10.2
8.6
8.6
9.4
7.2
7.3
2.2
42.6
41.0
37-7
40.4
39.9
38.4
39.8
38.2
40.2
36.6
39.2
38.8
37.1
39-6
37-5
37-4
40.1
39-5
51.6
54.3
53.8
53-5
52.3
52.4
50.9
52.7
46.1
46.2
46.2
46.7
42.0
42.8
43.7
42.3
48.2
52.8
5-8
4.7
8.5
3-7
5-4
7-1
5.2
3-4
3-5
6.4
4.3
4.3
12.3
9-0
9.4
13-1
4.4
5-5
Ultimate
analysis, %
Sulfur
Hydrogen
i
fe
I
•H
Z.
1
Ash
Btu softening Free
as Btu tempera- swelling
received dry ture,P° index
Hardgrove
grindability
index
(continued)
.6
.5
.5
1.0
.5
.5
.5
.6
.5
.6
.4
.7
.6
1.7
.5
.9
.4
5-1
-
5.0
5.7
5.6
5-5
-
-
5.9
5-7
5-9
6.1
5.5
5.8
5-7
5-5
5.8
5.6
78V3
-
72.6
77.8
76.9
75-7
-
-
68.2
65.1
67-7
67.7
62.1
64.0
74.4
62.7
69.6
76.6
1.3
-
1.5
1.6
1.5
1.5
-
-
1.5
1.5
1.4
1.5
1.4
1.3
1.5
1.5
1.5
1.7
12.9
-
14.2
10.2
10.1
9-7
-
-
20.4
20.7
20.3
19-7
18.1
18.2
18.5
16.3
18.3
10.0
11,290 12,960 2,720
11,390 13,210 2,540
10,990 12,370 2,900
14,640 - - -
14,650 - - -
14,790 -
14,060 - - -
13,760 - - -
12,500 - - -
13,320 -
12,540 -
12,650 - - -
12,830 - - -
12,740 - - -
12,690 - - -
13,050 -
12,960 - - -
14,620 - - -
59
57
55
-
-
—
-
-
-
-
-
-
-
-
-
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
County
las
Animas
Pitldn
jr
o teld
Delta
II
Fremont
n
Gunnison
Pltkln
n
n
Weld
Coal
field
or
town
Mine
Proximate
analysis , *•
1
Date £
of 3 '.
analy- S
Name sis seam £ :
Frederick Frederick 3.9
Raton
Dutch Coal 5.2
Creek Basin
Puritan Unknown 19.7
Grand
Mesa
Bowie
Canon
City
Tl
Florence
Crested
Butte
Somerset
Carbon-
dale
n
it
Walsen-
Burg
King
n
Corley
Ho. 2
Pioneer
Vento
Bear
Edwards
Thompson
Creek No. 1
Thompson
Creek No. 2
Thompson
Creek No. 3
Eagle
3-3
4.9
9.5
10.9
9.4
6.3
6.4
3-5
3.1
2.3
21.1
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
County
Coal
field
or
town
Mine
Proximate
analysis, "
g
•e
Date b
°f • «
analy- 3
Naroe sis Seam £
%
•H
1
%
s
1
Ultimate
analysis ,
1 £ 1
%
c? g, Btu
S & ^ ,
z o received
" COLORADO (continued)
Vfeld
H
H
n
Ftemont
n
n
n
tt
it
it
H
n
ft
Gunnlson
ti
ti
ti
Rio-
Bianco
tt
»
Boulder
Meld
it
Erie
»
Florence
tt
u
n
ti
tt
n
ii
it
tt
Somerset
ti
ti
it
Rangely
ii
ti
Eagle
K
Imperial
n
Beer Strip
No. 2
n
n
Canon Monarch
No. 4
«
H
Corley Strip
Double Dick
n
Pioneer
Canon
Hawk's Nest
ti
n
u
White River
11
22.0
22.7
21.5
19.0
8.3
8.8
8.8
12.1
12.1
12.7
11.2
11.0
10.1
10.7
4.8
5.1
5.0
6.6
11.7
11.2
12.3
37-7
37-9
38.1
38.1
1(0.2
39.7
37.8
38.5
39.0
36.1
37.1
37.1
31-5
38.3
72.5
42.2
12.0
42.0
38.0
37-7
37-9
55.6
51.2
56-3
54-9
50.1
50.5
15.8
51-7
51.1
50.0
50.8
51.8
15-9
52.6
53.7
54. n
54.5
51-3
55-7
53.8
51.1
6.7
7.9
5-3
7-0
9-7
9-8
16.1
6.8
6.9
13.6
11.8
10.8
19.6
9.1
3.8
3.1
3-5
3-7
6.3
8.5
8.0
.4 - -
.4 - -
.2
.4 - -
1.3
1.3
1.4
.7 - -
.7 - -
.9 - -
.5 - -
.4 - -
!l - -
.4
.4 5-5 79-2
.5 - -
-5 - -
.4 5.0 72.6
.5 - -
.5 - -
9,680
9,460
9,890
10,030
11,600
11,430
10,520
11,140
11,120
10,210
10,530
10,730
9,640
11,000
13,380
1.7 9.8 13,100
13,390
13,060
1.5 14.2 11,210
10,990
10,830
Ash
softening Free
Btu tenpera- swelling
dry ture,F° index
12,420
12,250
12,610
12,380
12,650
12^40
11,530
12,720
12,700
11,700
11,930
12,050
10,750
12,330
14,060
11,110
14,100
13,990
12,690
12,370
12,350
_ —
2,170
-
2,050
2,050
2,130
2,120
2,310
2,280
2,310
2,360
2,150
2,200
2,160
2,180 3
2,170
2,170
2,900
2,730
Hardgrove
grindablllty
index
™
-
™
15
17
42
51
"
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
VJ1
ro
County
Coal
field
or
town
Mine
Proximate
analysis, J
I
Date
of
analy-
Name sis Seam
1 Moisture
Volatile
° !
•H M r\
PC. < 0
COLORADO
Routt
Delta
"
Fremont
n
ft
Gunnison
"
"
Mesa
Routt
ft
Weld
tt
"
n
Mesa
V
n
Oak Creek
Bowie
ft
Florence
n
n
Somerset
tt
n
n
Palisade
Oak Creek
n
n
Erie
"
n
n
Palisade
"
"
Edna
King
n
Pioneer
Canon Prep.
Plant
n
Vento
Bear
ft
tt
ft
Roadside
Edna
It
Energy
Eagle
n
Inperial
n
Roadside
"
"
Uncor-
related
ti
ti
t!
11
Juanita C
**
n
"
Cameo
Wadge
"
n
Uncor-
related
"
n
n
Cameo
n
ti
7-7
1.1
1.6
9.7
10.6
10.5
5.9
6.1
5.5
7.8
8.1
8.7
8.9
10.1
21.2
22.1
21.3
22.7
8.2
9-1
8.1
11.7
12.1
11.1
38.6
37-1
37.1
11.8
39.9
10.3
39-9
38.1
11.1
10.9
11.3
39.1
38.9
38.6
38.6
38.2
39.3
38.1
18.9
53.5
52.7
52.1
50.1
50.8
55.1
52.9
52.6
52.6
51.8
19.0
19-0
50.7
55-7
55.1
56.6
51.8
18.5
51-1
17.2
9.1
1.1
6.2
9.3
12.5
12.1
2.8
7.2
7.1
7.5
10.1
9.6
10.1
8.0
5.2
6.0
1.8
6.6
13-3
9-3
11.7
Ultimate
analysis.
\ 1 I
(continued)
.6
.5 5-6 78.0
.6
.1
.1 - -
.1
.5 - -
.6
.5 - -
.6 - -
.6
.7 - -
.7 - -
.5 - -
.3
.3 - -
.3 - -
.3 - -
.8 - -
.7 5.0 73.2
.9
<
g a Btu
2: o received
11,500
1.6 9-9 13,130
13,080
11,070
10,510
10,650
13,160
12,510
12,610
12,210
11,670
11,210
11,110
11,380
9,910
9,710
9,870
9,550
11,230
1.5 10.3 11,610
10,920
Ash
softening Free Hardgrove
Btu tenpera- swelling grindabillty
dry ture,7° index index
12,170
11,000
13,710
12,260
11,790
11,900
13,980
13,320
13,310
13,210
12,700
12,310
12,230
12,660
12,620
12,170
12,510
12,350
12,230
12,810
11,920
2,190
2,910
2,910
2,390
2,210
2,190
2,570
2,650
2,620
2,520
2,890
2,910
2,600
_
2,060
_
2,070
2,910
2,550
2,790
-
_
1 1/2 18
_ _
-
_
_ _
_ _
2 1/2 51
2 53
_ _
_ _
15
_ _
— _
_ _
-
1 i/2 51
.. _
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
00
Coal
field
or
County town
Mine
Proximate
analysis, <
!
Date |
of 3
-, w
analy- -H
Name sis Seam s
Volatile
a
O
1
Sulfur
Ultimate
analysis , %
Hydrogen
Carbon
p CJ
1 1
Btu
as
received
Ash
softening Free
3tu tenpera- swelling
dry ture.F0 index
Hardgrove
grindability
index
COLORADO (continued;
Jfoffat Craig
Fremont Florence
Weld Erie
n
tt
„
it tt
ii tt
tt it
n it
Montezuma
it
tt
ti
n
n
n
ti
n
it
n
n
Wise Hill
No. 3
Canon Monarch
No. 1
Eagle
n
Inperial
ii
Washington
n
tt
n
n
n
Ofodd
IT
II
tt
Jackson
Tl
II
tl
tl
Cushman
u
«
16.0
12.7
20.7
22.6
21.7
21.7
23.1
23.9
23.2
21.5
21.1
21.1
11.0
13.1
12.1
12.1
12.2
12.3
13.8
12.8
_
11.6
_
-
39.TT
36.0
38.1
38.2
38.3
38.5
37.9
37.7
37-7
37-7
37.3
37.2
10.3
39.6
39-7
37.7
11.3
12.2
10.7
11.3
17.1
50.7
38.8
13.8
11.6
51.8
51.0
56.1
55.3
56.9
51.9
56.9
56.8
55.6
56.1
56.1
56.1
12.2
39.2
11.2
11.1
10.1
10.5
39.9
10.2
16.1
19.3
12.7
18.1
52.1
5.8
13.0
5.5
6.5
1.8
6.6
5.2
5-5
6.7
6.2
6.6
6.7
6.5
7.6
7.0
6.1
6.1
5-0
5.6
5-7
6.5
6.9
7.8
.5
.8
.1
.1
.3
.3
.3
.1
.1
.1
.5
.1
0.8
.7
.7
.6
0.1
.5
• 5
.5
.6
.6
0.6
.7
.7
5.1
1.7
_
_
-
_
-
_
-
_
-
_
—
5-9
6.0
-
-
-
6.1
5.1
5.7
6.1
5-7
6.2
72.8
66.9
—
-
-
_
-
_
-
-
-
_
—
63.1
61.1
-
-
-
63-5
72.8
77.8
61.0
72.1
78.5
1.5 It. 3
1.0 13.6
_
-
-
_ -
— -
_
-
-
-
_
— -
1.1 21.6
1.1 21.5
-
-
-
1.3 27.9
1.6 13.2
1.6 11.2
1.1 20.7
1.6 11.8
1.7 12.9
10,630
10,180
9,970
9,620
9,860
9,710
9,710
9,550
9,510
9,100
9,110
9,320
11,630
11,150
11,360
11,390
11,360
11,520
11,120
11,360
13,020
13,920
11,180
12,990
11,090
12,660
11,660
12,580
12,110
12,600
12,110
12,620
12,560
12,380
12,150
12,390
12,320
-
-
-
-
-
-
-
-
-
-
-
-
-
2,260
2,310
_
2,040
- -
1,990
2,010
2,020
2,020
2,020
2,020
2,020
-
— ~
- -
- -
- -
- -
— —
. — -
- -
- -
— —
— —
— ~
-
16
-
-
-
—
:
-
48
-
~
-
*••
-
-
-
-
—
~
-
-
~
—
~
-------
Table G-l (continued). WESTERN GOAL COMPOSITION & PHYSICAL PROPERTIES
-Cr
v_n
-Cr
County
Big Horn
n
n
n
ft
tt
n
n
it
it
ti
Beaver-
bead
Blalne
n
M
tt
"
tf
Coal
field
or
town
13 mi SE
of Lodge-
grass
15ml SE
of Lodge-
grass
tt
it
n
n
n
Decker
Medicine
Lodge
Zortman
"
lanttoky
Indian
Res.
Vlrgelle
Maddux
Mine
Proximate
analysis , ?
1
Date |j
of ^
analy- 3
Name sis Seam S.
Prospect 1967
" 1967
1%7
1967
" 1967
Cow Gulch 1967
Prospect
Prospect 1967
1967
1967
1967
Stroud Ck 1967
Kendrick
Tongue 1967
River
Peterson 1967
Bros.
John 1967
McClellan
Ruby 1967
Gulch
No. 2 1967
1967
Deda 1967
Bryan 1967
McSharry
22.6
17.0
16.9
24.6
17.4
21.6
18.7
17.4
22.5
24.2
28.8
23-9
14.6
19.6
22.6
22.3
11.9
18.2
8.2
Volatile
41.2
37-1
39.8
43.6
37.7
38.8
36.4
37-7
41.6
4l.2
41-5
40.3
35-2
36.6
33.9
34.9
37.8
35.8
33.1
§
i
T-l
fe
51.1
4717
47.1
37.0
54.6
54.9
57.3
58-3
51-9
52.1
53-9
53-7
47-3
50.6
46.0
14.1
47.7
50.4
49.0
.e
3
1 Sulfur
Ultimate
analysis, %
'O lj -P
5 3 z
x" as
o received
MONTANA"7*!"
7.7 0.7 - -
15.2 0.6 - -
13-1
19.8
7.7
6.3
6.3
4.0
6.5
6.7
4.6
6.0
17.5
13.1
20.0
21.0
14.5
13.8
17-9
0.4
0-5
0.6
0.9
1.0
0.4
0.4
0.5
0.5
0.9
2.3
0.8
0.9
0.8
0.7
1.0
0.9
_ _ _
2.8 54.9 0.9
4.2 71-5 1.1
_ _
_ - _
_ _ _
4.8 70.0 1.3
_ _ _
_ _ _
— - _
— - —
_ _
4.2 58.1 l.il
2.5 58.8 1.0
4.4 65-0 1.5
_
_
21.5
_
—
_
16.7
_
«
_
_
14.5
22.5
14.3
8,810
8,600
8,350
6,210
10,120
9,020
9,890
10,280
9,090
8,940
8,230
9,380
9,330
8,810
7,600
7,810
9,120
10,230
Ash
softening Free Hardgrove
3tu tenpera- swelling gr-lndability
dry ture.F0 index index
11,380
10,350
10,050
8,230
12,260
11,500
12,160
12,450
11,730
11,790
11,570
12,320 2,130
10,920
10,950
9,810
10,040
_ _
11,140
11,140
_
-
_
_
_
_
_
52
„
^
_
_
_
_
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
Coal
field
or
County town
Mine
Proximate^
analysis , *
I
Date £
°f U
analy- -g
Name sis Seam &
-0)
i~t
•H
S
g
3
o
£
&
C rH
s. £
Ultimate
aiiiilyois, t
g
a
I
I
te
.p
•H
z
1 ^s
o received
Ash
softening Free Hardgrove
3tu teiqpera- swelling grindability
dry ture,F° index index
MONTANA (continued)
Blalne Cleveland
" Ada
" Chinook
)i t*
-tr
\jl " E Har-
vjl lem
" Chinook
n n
it n
ii ii
ii n
tt "
" Harlem
" Chinook
ii n
Broad- 1 ml W
water of Lom-
bard
n
ii
ii
Lombard
Cook
Gibbits
Roder
Roder
Prospect
Raeder
Govern-
ment
Turtbler
Kerr
Milk
River
Milk
River
Sards &
O'keef
Matherson
Prospect
McDaniels
Leabo
n
Hegg
II
11
Western
Montana
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
18.8
16.8
23.1
21.4
21.0
23.8
21.4
20.5
25.6
26.0
22.9
23-3
30.0
26.7
23.6
2.8
3-7
3-0
3-0
3-3
3.2
38.8
33.5
34.6
35.6
36.4
38.1
33.9
36.2
35.9
38.6
37.3
38.9
57.3
35-0
35-0
25.2
26.7
20.3
24.8
24.4
20.7
49.7
52.6
52.7
53-0
50-5
47.2
52.3
49.4
51.3
51-9
51.0
43.2
25.7
54.6
48.7
44.2
54.0
40.7
50.1
51.4
41.1
11.5 0-9
13.8 1.4
12.7 0.7
11.4 0.7
13.1 0.8
14.7 0.9
13.8 0.8
14.4 1.0
14.4 1.0
11.8 0.7
9-5 0.6
17-9 0.9
17.0 1.5
9.4 0.9
16.3 0.7
30.6 8.5
19-3 7.3
39.0 7.2
24.5 8.3
24.2 10.8
38.2 7.4
4.5
4.4
4.3
4.2
4.3
4.3
4.5
-
4.2
3.1
4.3
3-8
-
2.9
3.0
65.4
61.1
65.7
59-2
65.2
66.6
67.0
-
58.5
57-7
67.1
59-7
-
45.5
48.5
1.4
1.6
1.5
1.9
1.4
1.5
1.4
-
1.2
1.1
1.2
1.3
-
0.5
0.5
13-5
15.8
14.6
19-1
15-5
15-1
17.0
-
17-3
19.6
17.1
18.1
-
4.2
2.4
9,140
9,563
8,570
8,940
8,780
7,580
8,650
8,320
8,510
8,433
7,798
6,910
8,440
7,673
10,000
8,105
10,570
10,620
8,670
11,250
11,500
11,500
11,370 . -
11,100
9,950
11,020
11,200
11,510 - - .
10,968
10,163
9,880
11,510
10,044
10,350
_ _
8,357
10,890
10,980
8,960
_
-
-
-
—
—
—
-
"
_
-
Bituminous
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
VJl
cr>
County
Carton
11
it
rt
it
n
tt
rr
tl
n
it
n
ti
rt
n
tt
n
FT
n
n
Tf
1
n
n
Coal
field
or
town
2.5 ml S
Joliet
Hye
Fpccnberg
n
Bridger
n
n
IT
Hye
Bridger
Red Lodge
n
n
"
if
11
ti
11
n
n
n
n
n
"
Mine
Date
of
analy-
Nane sla Ses
§
Moisture
Proximate
analysis, %
g
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
County
Carton
n
it
it
tt
n
tt
n
n
tt
it
it
tt
it
tt
"
ti
ti
Coal
field
or
town
Bearcreek
3/4 ml NW
Bearcreek
n
tt
Red Lodge
n
ti
ii
n
it
M
ti
ti
11
ti ~
2 ml W of
Bearcreek
Washoe
II
II
Mine
Mane
Proximate
analysis ,
I
Date £3
analy- -3
sis Seam £
Red Lodge 1967
No. 4
Interna-
tional
it
IT
It
tt
Snoke-
less &
Sootless
n
n
n
tt
it
"(deep)
n
tt
Brophy
Washoe
No. 1
Washoe
"
It
Roadside
19D/
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
10.4
11.1
12.5
11.7
9-3
11.7
10.9
11.1
9-3
10.5
10.5
11.8
lo.l
11.5
11.2
10.9
9.3
10.5
10.9
8.7
10.5
11.0
10.4
10.5
8.9
0)
t- 1
•H
1
37.7
~"
38.6
37.6
38.3
37.8
39-2
"~
42.6
40.0
38.7
37.8
38.5
37.6
37.6
38.3
38.7
37.6
a
o
I
*
1
Ultimate
analysis, %
H
I
I
•H
12
o
MONTANA (continued)
49.8 12.5 2.5 - -
51-9
50.6
50.6
56.6
51.5
50.4
52^5
56.6
53.6
52.8
52.8
50.1
48.8
48.9
9-5
11.8
U.I
5.6
9.3
7.0
6.6
8.8
5.6
7-9
9.6
9.6
11.6
12.5
13-5
1.9
2.2
2.0
1.0
1.6
2.1
1.4
1.2
1.0
1.5
1.8
1.3
3-2
1-3
4.3
4.8
4.6
4.8
5.0
-
-
5-0
4.7
4.9
4.9
4.3
68.6
65.6
67.7
73.0
-
-
73.0
69.8
65.3
66.8
65-5
1.9
1.5
1-9
1.9
-
-
1.9
1.7
1.4
1.4
1.6
13-3
14.3
12.5
13-5
-
-
13-5
12.9
13.6
_
_
_
12.1
10.8
Btu
as
received
10,590
10,800
10,660
10,760
10,470
10,510
11,360
10,820
11,190
10,930
10,920
11,010
10,240
11,220
10,870
11,360
11,190
10,910
10,840
10,604
10,840
10,480
10,040
10,750
10,530
10,470
Ash
softening Free
Btu tenqpera- swelling
dry ture ,F° index
11,760
12,190
11,550
11,910
12,750 2,080
12,170
12,220
12,480
12,680
12,240
12,750
12,340
12,200
12,160
11,619
_
- - -
-
- - -
11,760
11,490
Hardgrove
gr-lndability
Index
-
_
-
-
-
-
-
-
-
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
-Cr
VJ1
oo
County
Carbon
n
n
n
n
n
n
n
n
n
n
n
ii
n
n
n
n
ti
n
IT
It
n
it
, "
t*
Coal
field
or
town
1 mi S of
Bearcreek
Washoe
1 ml W of
Bearcreek
n
n
Bearcreek
1 ml W
Bearcreek
1-5 ml W
Bearcreek
n
Mine
Proximate
analysis, %
B
Date | 3
Of 4J i>
analy— -H *-*
Name sis seam i :>
Poster
Gulch
Mo. 2&3
North-
side
n
South-
side
It
It
Bearcreek
Prospect
Bearcreek
n
n
No. 2
n
n
n
it
"
"
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
9.0
9.7
10.1
10.2
10.1
10.3
10.0
9.8
10.0
10.2
10.1
9.6
9.9
9-8
10.1
9.7
8.6
9.8
10.1
10.4
10.7
U.I
10.8
10.7
ir
39-7
41.5
39.0
38.4
37-7
_
37-7
38.5
41.4
39-8
37-9
38.5
38.7
-
_
-
39.5
-
Ultimate
I
3
*H [Q 3 ^) CO "H
to < to X O Z
M3HTANA
47.4 12.9
49.1 9-4
51.1 9.9
51.9 6.7
49.7 12.6
_
49.5
52.3
51.9
51.3
47.5
52.3
ig.o
—
-
_
-
50.5
-
_
12.8
9.2
6.7
8.9
14.6
9.2
12.3
_
_
_
10.0
-
(continued)
3.3 - -
1-5
1-7
1.9
2.5 4.6 65.7
_
2.5
2.4
1.6
1.8
3-0
2.4
2.0
_
_
_
_
1.8
-
—
4.7
4.6
4.8
4.9
4-5
4.6
_
-
_
_
_
4.9
_
66.3
66.7
66.3
68.3
62.3
66.7
_
_
_
_
_
6S.'t
-
1.6
_
1.6
1.6
1.6
1.6
1.6
1.6
_
_
_
_
_
1.0
g) Btu
j< as
o received
13.0
_
12.1
15.6
19.0
14.5
14.0
15-5
_
_
_
_
13.0
11,054
11,020
11,030
10,550
10,620
10,640
10,590
10,540
10,570
10,620
10,590
10,880
11,190
10,830
10,180
10,880
10,680
10,970
10,720
10,850
10,590
10,780
10,970
Ash
softening Free Hardgrove
Btu tempera- swelling grindability
dry ture,P° index Index
12,21(6
12,270
12,280
11,700
_ _ _
11,740
12,070
12,450
11,990
11,140
12,070
11,880 " -
_ _ _
_ _ _
_ _
-L2.U6U
-
-
_
_
_
_
_
_
_
_
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION 8= PHYSICAL PROPERTIES
County
Carbon
11
n
»
ti
Coal
field
or
town
Mine
Proximate
analysis, *
g
.a
Date §
Of 4J
analy- 3
Name sis Seam £
1-5 ml W No. 2
of Bearcreek
n
ii
n
Bearcreek
1.5 ml W
n
n
New
NO. 2
1967
1967
1967
1967
1967
1967
10.7
11.1
10.8
10.7
10.5
9.9
Volatile
a
0
I
C rH
3. S
Ultimate
U) c
o o
5? 0
PBMTANA (continued)
_
38.2
39.4
38.9
_
51.6
50.3
48.6
_ —
10.2 1.7
10.3 2.0
12.4 1.9
— —
4.8 68.1
- -
-
<
tt) C
•p >> as
z o received
10,710
10,820
10,550
1.8 13.4 10,800
— — ~
10,615
Ash
softening Free
Btu tempera- swelling
dry ture,F° index
_
- — -
12,080
_ — —
11,786
Hardgrove
grindability
Index
-
~
-
-
of Bearcreek
n
n
n
Washoe
1-5 ml S
of Foster
1.5 mi S
Foster
Mine
Nelson
1967
1967
1967
9.2
9-0
9.6
-
39.7
40.8
-
47-4
52.1
-
12.9 3.3
7.1 2.6
-
-
-
11,086
_
_
12.200
-
- - -
-
-
-
of Bearcreek
Carter
tt
Cascade
M
tf
tt
••
NW Camp
Crook S.D
n
Eden
Great
Falls
Eden
n
Sand
Soulee
Stockett
Homer
Kerr
Car-
ville
Deep
Creek
Patterson
Bickett
Gerber
Cotton-
wood
1967
1967
1967
1967
1967
1967
1967
1967
41.3
39-0
4.5
5-9
6.2
4.8
7-5
6.0
42.0
37-1
28.8
34.8
co mifN
coco cr\
CVJ C\J O
30.3
45-8
39-2
50.2
52.5
55.5
48.5
55.6
54.7
12.2 1.1
23.7 2.6
21.0 4.3
12.7 4.3
15-7 4.7
23.0 3.0
14.9 2.5
15-0 2.5
-
_
3-9 61.7
4.5 68.4
4.0 65.7
4.0 59.9
4.2 67.3
4.0 67.7
6,190
5,600
0.9 8.4 10,472
0.9 9.2 11,470
1.0 8.9 10,940
0.8 "3-4 10,040
1.0 10.1 11,010
1.0 9.8 11,150
10,550
9.190
10,971
12,180
12,990
10,548
11,900
11,870
-
-
-
-
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
County
Coal
field
or
town
Mine
Proximate
analysis , "!
I
Date S
of 5
analy- •*
Name sis Seam s
Volatile
8
e
1
MONTANA
Cascade
n
n
11
S
o
«
n
Chouteau
n
it
n
n
n
n
n
n
"
n
Belt
n
it
n
Arming-
ton
it
Slums
Virgelle
16 ml SE
of Vlrgslle
mad
Big Sandy
n
n
n
n
Havre
Big Sandy
Box Elder
Qrr
Anacon-
n
Mlllard
Richard-
son
HH1
Rlflraer
Price
Serton
Deda
Lehfehit
VanBus-
JdLrk
Maclc
Mackton
11
n
Schew
Hygard
Lance
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
10.9
7.1
6.4
4.6
3.5
9.6
8.9
17-5
18.2
13-9
19.8
14.9
13.0
12.4
12.1
21.2
14.4
7-9
22.7
27.4
29.4
32.0
27.4
25.7
38.1
36.6
35.8
37.1
38.4
40.6
J)1.7
42.1
39.5
39-9
38.8
-
47.1
53.1
48.3
48.4
52.4
57-8
43.2
49.9
50.4
42.7
43.0
51-9
46.1
40.9
47.4
46.3
53-9
-
30.2
19.5
22.3
19.6
20.2
16.5
23.1
13-5
13.8
20.2
18.6
7-5
12.2
17-0
13.4
13.8
7-3
-
rH
Ultimate
1
i
Nitrogen
1 Btu
g as
6 received
Ash
softening Free
Btu tempera- swelling
diy ture.P0 Index
Hardgrove
grindablllty
index
(continued)
2.0
1.8
2.2
3.8
3-9
2.2
0.7
0.7
1.0
0.9
1.1
0.5
0.6
0.8
0.9
1.1
0.7
-
2.8
3-9
3.4
3-9
3-6
-
4.5
4.4
_
_
4.4
_
_
4.5
_
4.8
-
53.4
62.5
60.0
-
63.8
65.0
-
66.0
65.0
_
-
68.8
_
-
63-5
_
69-3
-
0.6
0.7
0.8
-
0.7
0.7
-
1.4
1.5
_
-
1.0
_
-
0.8
_
1.0
-
11.2
11.6
11.3
7.5
12.0
-
14.0
14.3
_
_
17.3
_
17-2
_
16.9
-
7,740
10,120
9,870
10,880
9-930
9,850
9,317
9,120
3,570
8,240
9,940
9,620
9,090
9,600
8,241
10,440
10,7^0
8,690
10,890
10,540
- - -
11,280
10,990
10,810
11,290
11,140
9,960
10,200
11,670
11,060
10,380
10,720
10,467
11,850
_
-
_
-
_
-
-
_
„
«
-
_
-
-
-
_
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
Proximate
analysis,
County
Coal
field
or
town
Mine
Name
Bate
of
analy-
sis seam
Moisture
Volatile
§
O
&
1
MONTANA
Custer
it
n
H
tl
n
n
M
it
it
ii
Daniels
u
Mizpah
Miles-
City
5 mi S
Miles City
Miles City
Washoe
1 mi N
Miles City
5 mi N
Miles City
Miles City
35 mi NW
Miles City
30 mi NW
Miles City
Scobey
n
KnJntz—
felt
Weaver
Old
Weaver
Stonn
King
Outcrop
Smith
Hedges
Kircher
Klrcher
McNamara
Olso
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
34.3
29-5
29.1
31-9
35.5
31.8
10.0
29.2
29.6
30.3
35-2
31-3
33-2
34.1
38.6
39.7
35.7
40.0
41.5
37-4
41.8
36.9
38.9
43.7
40.2
38.7
37-9
37.6
48.4
48.0
43.1
53-1
44.8
40.8
47.5
50.1
46.8
45.0
55-1
51.3
48.5
48.6
13.0
12.3
21.2
6.9
13.8
13-8
10.7
13.0
14.3
11.4
4.7
10.0
13-6
13.8
Ultimate
ar£-;.Ji3 ,
§ p 8
*-• _h -P
^ 3
(continued)
0.8
1.0
0.8 3-3 56.6
0.4
0.6
1.0
2.0
1.1
1.0
0.9
0.5
0.7
3.2 3-9 62.2
0.6 3.7 63.8
y § Btu
-p >> as
z O received
9,980
7,720
0.8 17-3 6,660
7,680
6,363
7,341
10,830
7,670
7,480
_
_
- - -
0.8 16.3 6,470
0.9 17.2 6,850
Ash
softening
Stu tempera-
dry ture,F°
10,640
10,950
9,400
11,286
9,866
10,755
12,040
10,830
10,630
-
-
-
10,298
10,400
Free Hardgrove
swelling grindability
index index
-
— -
-
-
-
-
-
-
-
-
— ~
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
County
Daniels
Dawson
IT
?T
tl
n
ft
n
n
11
n
n
n
n
TT
n
n
Fallen
n
if
Mine
Proximate
analysis , *•>
I
Coal Date
field of
or analy-
tcwn Name sis Seam
E. Soobey
GleniLve
n
n
n
n
n
ti
ft
n
n
n
- Sidney
Lignite
Bloonfield
n
n
n
Ooaloreek 1967
Outcrop
Peuse
Snyder
SBith
it
Chupp
Albrecht
Chinney
Rock
Carroll
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
Coal Bank 1967
4.5 ml NW
Canp Crook
ti
Spring
[forner
Kerr
Prospect
1967
1967
Q) 13 3
C rH O
*> -P T)
5 5 S x
3 $ Si «
11.3
26.8
35.8
31.9
31.6
33.6
34.9
31.3
33.1
33.1
32.1
32.6
31.5
38.3
36.3
33.7
33-0
38-7
11.3
39.0
39.2
43-9
40.8
41.5
54.0
44.7
66.8
61.7
45.3
59-5
37-7
37.0
_
38.5
41-5
41.1
38.1
44.1
42.0
37.1
Sulflir
Ultimate
analysis, *
Hydrogen
c So
Q &
1 Btu
§ 33
" received
MONTANA (contimed)
45.0 15-7 0.9 -
46.7
46.2
49.9
35-0
44.9
20.8
28.4
42.3
31.2
50.4
50.4
_
48.7
46.9
48-7
53-7
40.9
45.7
39.2
9-3
13-0
8.6
11.0
10.lt
12.4
9-9
12.4
9.1
11.9
12.6
_
11.8
11.6
10.2
8.2
15.0
12.3
23.7
0.4
2-9
1.2
1-7
1.2
2.0
1.2
1.5
1.0
2.0
1.9
_
0.4
0.9
0.7
0.5
0.5
1.1
2.6
_
3-9
-
4.2
3.6
3.9
3-7
-
-
4.2
-
4.1
-
-
-
_
-
-
_ _
63-8 1.1
-
64.8 0.9
60.8 0.9
64.0 0.9
63.9 0.8
- _
- -
- -
71.6 1.0
-
65.5 i-o
-
-
-
_ _
-
-
_
15-3
-
17-5
23.1
16.8
20.6
-
-
-
15.7
-
17.2
-
-
-
_
-
-
5,675
..
6,830
-
7,090
6,692
6,984
7,337
7,774
7,110
7,380
6,880
6,530
6,780
7,090
7,400
6,020
6,190
5,600
Ash
softening Free Hardgrove
Btu tenpera- swelling grtndabillty
dry ture,F° index index
9,670
_ ' — —
10,6*40
_ _ _
10,833
10,087
10,726
10,674
_ _ _
11,614
10,470
10,950
_
10,590
10,650
10,690
11,050
9,820
10,550
9,190
_
_
-
_
-
-
-
-
-
-
-
-
_
-
-
-
-
-
—
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
OJ
County
Fergus
«
n
ti
n
ti
tt
it
tt
ti
ti
it
ti
ti
Coal
field
or
town
Lewistown
Moore
Hock Creek
Forest-
grove
Lewistown
Wlndham
tt
Lewistown
ti
Giltedge
Lewistown
Forest-
grove
Mine
Proximate
analysis , *
I
Date |j
of 3
analy- -3
Name sis Seam g
Knox
Rand
Cooper
Sharp
Hobson
Peiper
Hughes
Seman
Spring
Ck.
Sheep
Hamilton
Black
Diamond
Gllffe
Gold Roof
Flaherty
Truss
it
Ben Hill
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
9-2
13-9
16.9
15.7
11.1
18.9
11.3
9-3
15.1
12.3
12.7
11.1
8.0
8.3
9.8
12.2
11.8
18.6
Volatile
32.7
30.5
36.1
35.2
33-6
31.0
29.1
32.6
33.1
32.7
33.9
31-9
28.9
32.6
31.8
37.5
37.3
30.2
§
•H
1
Sulfur
Ultimate
analy. 'is, %
Hydrogen
i
MONTANA (continued)
47.7 15-6 10.3 -
48.6 20.9 7.0
54.8 8.8 3-6 4.5 70.1
51.8
52.5
59.6
52.4
50.6
56.8
58.5
55-9
56.4
60.9
58.5
46.8
54.1
51-5
59.1
12.9
13-9
9.1
18.5
16.8
9.8
9-1
10.2
11.7
10.2
8.9
21.1
8.4
11.2
10.4
3-3
5-1
3.1
5-1
1.1
5.1
1.4
4.2
1.3
4.8
1.5
5.1
1.5
3.6
4.6
-
4.2
3.8
3.7
4.1
4.4
4.1
4.3
4.6
4.8
4.7
-
-
66.5
70.7
60.3
61.1
72.2
69-7
70.5
72.3
73.0
69.6
-
Nitrogen
0.8
-
0.9
0.8
0.8
0.9
0.8
0.9
0.8
0.8
0.9
0.9
-
& BtU
& aS
o received
12.2
-
9.1
11.9
11.7
9.8
7.1
9.3
9.1
8.9
8.4
10.0
-
9,670
9,690
10,310
-
10,511
9,750
9,220
10,215
10,015
11,150
10,900
10,429
11,510
11,770
9,510
11,360
11,030
9,910
Ash
softening Free Hardgrove
Btu tempera- swelling grindability
dry ture,F° index index
10,650
11,250 - -
12,400
- -
11,850
12,020
10,390
11,257
12,510
12,720
12,190
12,150
12,590
12,810
10,550
12,940
12,500
12,170
-
—
-
—
-
-
-
-
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
County
Coal
field
or
town
Mine
Proximate
analysis, <
!
Date 5 <-<
of -§S
analy- 3 3
Name sis seam s. >
1
1
•H
PL,
1
MOOTANA
Fergus
n
n
n
n
it
it
n
n
"
n
n
n
n
it
n
n
n
"
n
11
Lewlstown
"
Glltedge
n
Maiden
Hilger
Winifred
n
11
n
11
n
n
n
Zortman
Winifred
"
n
ft
n
Zortnan
Nevln
Brew 4
Parson
Sherman
Shipley
Mace
Stone
Truss
Outcrop
Prospect
Opencut
"
Outcrop
"
Hahn
Ruby-
Gulch
Mills
Opencut
Outcrop
"
Calder-
xood
Open-
Prospect
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
6.9
12.6
15.6
7.4
2.8
23-1
24.9
27.6
24.8
24.0
33-9
29.9
22.2
24.2
22.6
23-5
19.0
20.4
31.2
22.8
12.5
30.7
30.6
32.1
28.4
28.2
43-5
40.4
39.6
36.1
37.8
39-5
39.8
37.4
36.7
33-9
37-1
36.8
35-9
39-0
35-9
35-5
45.8
49.7
58.9
59.9
55-9
39.8
43.4
41.6
51.3
42.9
41.0
48.7
47.7
52.3
46.0
42.8
41.2
46.0
48.5
48.8
44.3
23-5
19.7
9.0
11.7
16.0
16.7
16.2
18.8
12.6
19-3
19-5
11.4
14.9
11.0
20.1
20.2
22.0
18.1
12.6
15.3
20.2
Ultimate
analy^i?, *
i! il
(continued)
5.9 - -
4.0 3-9 62.7 0.9
2.2 4.0 67.2 0.8
2.8 - -
5-0 - -
1.4 - -
0.8 - -
0.7 - -
0.7 4.3 65.2 1.6
2.5 - -
0.9 - -
1.1
1.6
1.0 - -
0.9 - -
1.1 - -
1.2
0.8
0.9
1.1 4.4 63-9 1-4
0.7 - -
|j Btu
& as
o received
9,412
8.7 9,396
16.7 9,545
10,863
11,722
7,750
7,910
6,631
15.7 8,338
7,531
5,371
7,344
8,449
8,470
7,600
7,481
7,843
8,194
7,038
13.9 8,480
8,350
Ash
softening Free
Btu teitpera- swelling
dry ture ,P° Index
10,110
10,750
11,317
11,731
12,064
10,080
10,520
9,153
11,090
9,907
8,131
10,472
10,852
11,170
9,810
9,774
9,681
10,292
10,226
10,980
9,540
Hardgrove
grindability
Index
_
_
-
-
-
_
_
-
—
-
-
-
-
_
-
-
-
-
-
-
-------
Table G-l (continued). V1ESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
Mine
Coal
field
or
County town
Fergus Zortn&n
Name
Date
of
analy-
sis Seam
Joe Shel- 1967
Proximate
analysis , *
co ro
*" •£ TS
5 3 S £
Q O -H M
£ > B. <
MONTANA
19.2 11.9 17.1 11.0
Sulfur
Ultimate
analysis, %
c c
I 1 I
1) Btu
g. as
5 received
Ash
softening Free
Btu terrpera- swelling
dry ture,F° index
Hardgrove
grlreJability
index
(continued)
0.9
_
8,810
10,900
-
leriberger
-Cr
VJ1
Flathead Flathead
raver
Gallatln Chestnut
Div. Trail
Outcrop
Beede &
Bally
1967
1967
22.2 11.8 16.8 11.1
2.1 16.7 71.8 8.5
2.9
0.9
_
3.9 82.7 1-3
8,801
2.7 11,090
11,307
11,390
-
-
Chestnut Mountain 1967
Side
Storrs
Garfleld Jordan
Glacier Cut Bank
Washoe 1967
Copper Co. No.3
Anaconda 1967
Washoe 1967
No. 1
(Hodsen)
Storrs 1967
No. 3
" 1967
Foster 1967
Prospect
» 1967
Prospect 1967
Allison 1967
5.1 28.5 39.1 32.1 0.1 3.8 53.5 0.9 9-1 9,030 9,550
1.8 31.5 38.3 30.2 0.5
6.3 - ----- - - H,160
5.8 35.2 53-6 11.2 0.5 5-0 73-5 1.1 8.7 12,280 11,680
1.1 30.9 36.9 32.2 0.5 1-0 53-0 0.7 9.5 9,095 9,187
U.O _ . _ - - - - - 11,860
28.3 36-9 16.9 lfi.2 0.6 - - - 7,360 10,270
31-3 35-8 11.8 19.1 0.5
16.6 35.0 18.1 21.5 0.7
7.8 32.8 37.2 30.1 1.9
8,707 9,115
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
County
Glacier
n
Golden
Valley
n
n
Granite
Hill
n
Coal
field
or
town
Brown-
ing
St. Marys
Painted
Rock
2 mi N
Lavlna
18 ml NW
lavina
Drunrnond
Havre
n
n
Box Elder
12 mi S
Havre
Mine
Name
Proximate
analysis , *
I
Date |
of 3
analy- S
sis Seam £
J. M. 1967
Stone
Prospect
Paisley 1967
Prospect
Shole
Bennett
Caldwell
Prospect
Statons
Clack
Electric
Prospect
Bpown
Schean
Prospect
Klimey
Barrotts
Alcott
n
Havre
Blue
Pony
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
8.0
7.0
11.6
10. M
10.4
19.4
29.2
25.6
22.8
8.4
19.0
21.2
21.1
21.5
21.1
24.7
22.0
7.9
11
rH
«H
«
1
38.4
34.4
36.0
34.7
33.1
46.8
37.7
37.6
38.0
19.0
33.4
39.9
38.0
37.3
35.0
37-0
30.5
8
1
•H
PC,
s:
w
<
MONTANA
48.0 13.5
51.0 14.6
45.6
48.5
49.0
32.2
52.8
52.6
44.8
71.6
43-7
46.3
48.3
45.3
51.4
49.0
56.2
18.4
16.8
17.9
21.0
9.5
9.8
17.2
9.4
22.9
13.8
13-9
17.4
13.6
16.0
13.3
1
Ultimate
analysis ,
bo C
£ 8
%
M C
O fli
£ 60
(continued)
0.9
1.1
2.0
1.9
1.7
1.0
0.8
1.0
1.2
1.8
1.1
1.0
0.8
0.9
1.2
0.8
-
-
4.6 64.0
-
5.3 57.0
4.5 65.0
4.5 66.0
4.1 61.1
4.1 61.5
-
-
1.6 11.0
-
0.8 14.2
1.3 18.7
1.4 17.5
1.1 16.5
1.3 19.0
Btu
as
received
11,047
10,870
10,010
10,220
10,100
8,700
7,840
8,290
7,900
11,170
7,480
8,240
8,420
7,850
8,170
7,930
8,210
10,740
Ash
softening Free
Btu tempera- swelling
dry ture,F° index
12,008
11,690
11,330
11,400
11,280
10,790
11,070
11,140
10,240
12,200
9,250
10,470
10,000
10,000
10,700
10,530
10,530
— — —
Hardgrove
grtndabillty
index
-
_
-
-
!
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
County
Hill
tt
II
ft
It
Judith
Basin
n
n
n
n
it
n
n
ft
ft
McCone
ti
1!
II
Coal
field
or
town
Havre
tt
Rudyard
n
Havre
Buffalo
n
Utlca
Windham
n
Geyser
Raynes
Pord
Geyser
Moore
n
Circle
II
II
ir
Mine
Proximate
analysis , •
1.
V V
Date £ 3
°f 3 S
analy- 3 -g
Mane sis Seam £ >
Project
n
n
tt
n
tt
Wheatman
Outcrop
Banks &
Stevem
Prospect
mi llama
Saager
Canyon
Showan
Hughes
Sanan
Meredeth
larson
Hollar
Knox
Sharp
Aus
Strip Pit
Stephen-
son No.
1967 "
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1
25-5
36.8
39.7
30.4
40.1
23.6
26.9
31.4
24.1
31.6
14.1
17.0
10.0
11.3
9-3
10.2
13-1
8.8
9.2
15-7
30.6
25.8
34.0
36.4
39.3
41-3
15.4
40.5
42.9
35-7
45.8
41.4
38.5
41.9
33-7
33.0
27.6
29.1
32.6
27.6
25.1
28.2
32.7
35.2
39.7
42.1
44.7
39-3
1
•8 £
S « =
<*• < &
Ultimate
analysis, %
Hydrogen
I
Nitrogen
g. Stu
x as
o received
M3NEANA (continued)
49.8 10.9 1-3 - - -
36.0 22.7 0.9 - - - -
10.4 u. 2 0.8 - - -
50.1 9.5 i.o - - - -
33-7 21.^ 0.7 - - - -
37.6
34.0
34.6
49.3
41.1
53.4
52.8
49.1
52.4
50.6
50.14
49.3
55.2
47.7
52.0
43.5
50.0
46.7
50.0
26.7
20.2
21.0
12.2
17.0
13-0
14.2
23-3
18.5
16.8
22.0
25.2
16.6
19.6
12.9
16.8
7-9
8.6
10.7
1.6
1.0
2.0
1.5
1.0
4.8
5-0
6.1
5.1
4.4
3.1
1.5
4.3
10.3
3.3
1.6
0.1
0.6
0.1
_
4.1
_
1.1
-
_
3.7
-
3-7
4.1
_
3-2
3-3
-
4.7
4.7
4.7
3.7
_
58.2
66.0
-
_
62.4
-
60.3
64.1
_
57.5
64.6
-
60.2
66.2
65.4
64.7
_
1.3
1.3
-
_
0.8
-
0.8
0.9
0.8
0.9
-
l.l
1.1
1.2
1.3
_
15.2
14.6
-
_
14.0
-
11.7
9.8
-
11.9
9.9
-
15.6
19.7
19.5
19.2
8,199
5,031
5,277
7,199
4,532
7,058
7,250
-
8,470
6,323
-
8,894
8,890
9.220
10,215
-
8,350
10,127
9,668
—
7,220
8,160
7,400
6,610
Ash
softening Free Hardgrove
Btu tenpera- swelling grindability
dry ture.P" Index Index
11,002
7,956
8,755
10,768
7,573
9,239
9,918
- - -
11,070
9,252
_
10,713
9,870
10,390
11,257
- - -
9,605
11,099
10,647
— — —
10,400
11,000
11,210
10,390
j
-
-
—
-
~
-
-
-
-
~
~
~
-
-
~
—
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
CTi
CO
County
Meagher
Hissoula
n
Mussel-
Shell
n
11
H
It
n
n
n
n
n
n
n
n
n
n
"
u
rt
"
n
Coal
field
or
town
10 mi S
Of Dorsev
Hissoula
n
Bun
Mountain
1!
n
n
n
n
n
it
Boundup
n
n
Klein
Roundup
™
n
n
it
n
Mine
Proximate
analysis, *
!
Date £
of $
analy- -H
Name sis seam S
Reese
Ifellgate
n
Vfestern
Coal No.
Vfestern
Coal No.
Big Vein
Gantar
Republic
No. 2
n
Roundup
No.3
It
tl
Republic
No. 2
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1
1967
2
1967
1967
1967
1967
1967
1967
1967
1967
6.7
25.2
21.7
17-0
16.9
18.2
16.0
I8.it
21.6
18.6
17.1
13-9
lit. 2
H.5
13-9
15.7
lt.0
11.7
11.9
17.0
10.5
11.7
11.8
Volatile
27.1
39.0
39.0
_
_
37.1
37.1
_
_
_
—
37.7
37-6
38.3
36.2
37-2
35.9
31.0
_
37-5
35.1
35.1
-
a
o
^
&,
i a
Ultimate
analysis , ^
I
g
Nitrogen
1, Btu
g> as
6 received
MONTANA (continued)
38.3 31.6 0.5 - -
31.8
3t.7
_
_
55-6
55.7
_
_
_
-
54.0
53.0
52.9
t9.3
511.9
57.5
56.7
_
52.8
51.3
55.1
-
26.2
26. U
_
_
7.3
7-2
_
_
_
-
8.3
9.1
8.8
11.5
7-9
6.6
9.3
_
9-7
10.6
9-5
-
1.0
1.1
_
_
1.1
0.6
_
_
_
_
0.7
0.9
0.8
0.9
1.2
0.8
0.6
_
0.7
0.5
0.5
-
_
3-7
_
_
4.6
4.7
_
_
_
_
1.9
1.8
1-9
1.5
1-9
5-1
1.8
_
_
-
-
-
_
51.8
_
_
72-9
73-3
_
_
_
72.2
70.8
71.7
67.1
72.6
72.8
72.8
_
_
_
—
-
_
1.0
_
_
1.2
1.2
_
_
_
_
1.3
1.3
1.2
1.1
1.2
1.2
1.1
_
-
-
-
-
_
15-9
12.9
13.0
12.9
13.0
_
_
_
12.5
12.8
12.6
11.9
12.2
13-5
11.1
_
_
-
-
-
8,539
_
6,727
8,597
8,352
10,190
10,510
8,638
9,016
9,892
10,280
10,890
10,600
10,670
10,010
10,720
11,160
10,080
11,110
10,290
11,010
11,090
10,990
Ash
softening Free
Btu tenpera- swelling
dry ture,F° index
9,151
_
8,933
— — —
— — «.
12,160
12,560
« _ —
_ _ _
— — _
12,650
12,350
12,480
11,630
12,710
12,980
12,550
- — _
12,100
12,330
12,560
_
Hardgrove
grindability
Index
-
-
_
_
_
_
_
_
_
_
_
_
_
_
.
_
_
_
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
vo
County
Coal
field
or
town
Mine
Name
Proxi-Tate
analysis , ?
1
Date
of
analy-
sis
jp
CO
Seam £
X
S
•H
1
13
a
1
MONTANA
Missel-
Shell
tt
tl
II
tl
It
n
it
ii
n
ii
tt
**
ti
n
n
it
ti
ti
it
n
ii
ti
it
ii
n
tt
it
Roundup
n
ti
ti
"
it
it
tt
ii
n
it
it
ti
ti
ti
n
rt
tt
ii
n
ti
ti
Tl
"
II
"
It
Square-
deal
n
n
It
It
it
Davis
Keene
Nles
Keene
Nles
n
Keene
Nles
Nles Bros
Nles
Nles Bros
Nies
Roundup
No. 3
Keene
Prospect
Ccmner-
clal
Roundup A
it
ti
it
11
tt
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
.1967
1967
.1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
12.8
12.6
11.8
12.2
12.1
12.2
11.5
13-5
12.3
11.9
12.3
12.6
12.0
12.1
12.7
12.0
12.2
12.1
13.6
12.1
12.7
11.3
15.0
13.7
12.9
13-3
11.1
13.6
_
_
-
_
35.8
_
36.9
38.1
-
-
_
-
35.5
-
36.5
-
73.2
-
37.7
_
32.9
32.5
_
_
-
-
-
38.0
_
_
_
_
51.5
_
55.5
52.6
_
-
_
_
57.9
-
51.9
_
55.8
-
51.1
_
58.3
60.6
_
_
-
-
-
52.7
_
_
_
_
9.7
_
7.6
9.0
_
_
_
6.6
-
8.6
_
7.6
-
8.2
_
8.8
6.9
_
_
-
-
_
9-3
Ultimate
analysis, 1
g
J| j?
rH *9
in S
(continued)
_" "
_ _
_ _
_ _
0.4 11.6
— _
0.9 -
0.6 -
_ _
_
_ _
_
0.5 1.9
0.5 1-7
_ _
0.1 1.7
- _
0.7 -
_ _
0.6 1.6
0.6 -
_ _
_
-
-
_
0.8 1.7
g
o p
I 3
_
— —
— —
_ _
72.6 1.2
_ _
-
_ _
_ _
_ _
_ _
_ _
73.9 1.2
73-5 1.2
71.0 1.2
_ _
-
_ _
73.6 1.0
_ _
_ _
_
_
_
71.7 1-1
I Btu
& as
O received
10,570
10,810
10,770
10,930
11.5 10,980
10,690
10,350
10,890
10,150
11,280
10,800
11,010
12.9 11,360
10,700
11.5 11,010
10,930
12.7 11,300
11,030
10,990
11,130
U.I 11,030
11,050
10,500
10,870
in, 810
10,630
10,570
12.1 10,690
Ash
softening
Btu tenpera-
dry ture,F°
_
_ __
_ _
12,530
12,UO
12,590
_ _
_ —
_ _
12,900
12,610
_ _
12,870
12,710
_ _
12,610
12,890
_ _
_ _
_
_
_
12,360
Free Hardgrove
swelling grlndability
Index index
_ _
_ _
-
_
_. _
_ _
— . —
_ _
_ _
_ _
_ _
— _
_ _
- —
_ _
— —
_ _
_
_ _
_ _
— —
_ _
_ _
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
Coal
field
or
County town
Missel- Roundup
Shell
n n
it
i
-fc" n
~~3 it
it
"
"
it
*
«
ii n
n n
it it
" tossel-
11 n
" Wolf
Spring
" Massel-
Shell
" Absher
n it
it it
mne
Proximate
analysis, %
!
Date |
analy- -H
Name sis seam £
Republic
tfo.l
Roundup
No.3
n
Republic
Jfo.2
n
Johnnie's
Gilbert
Crawford
Nevorblg
& Ttodd
Grant
Prospect
Surface
Prospect
Robins
Prospect
Carpenter
Creek
11
n
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
13.4
12.8
13.8
13.1
13.2
12.7
12.0
21.1
13.1
11.9
12.3
13-7
13-4
14.6
16.9
20.7
16.7
20.7
22.8
20.4
20.3
20.3
Volatile
32.5
_
33.1
32.9
-
_
-
_
36.3
32.5
37.4
38.5
37.3
36.1
33.4
33-5
35.0
-
_
34.7
8
O
U
x a
$ 2
M3NTANA
60.3 7". 2
_
57-3
58.2
-
_
_
_
54.2
59-9
55.0
53.6
54.0
56.3
57.7
58.3
59.0
-
-
60.4
_
9-6
8.9
-
_
_
_
9-5
7.6
7.6
7.9
B.7
7-6
8-9
8.2
6.0
-
_
4.9
intimate
analysis ,
a a
P
§ 3?
i
t
Nitrogen
1
(continued)
0.5 - -
_ _
0.6 4.8
0.6 4.7
- -
_ _
- -
_ -
0.5 4.8
0.6 -
0.5 4.7
0.7 4.8
0.6 4.8
1.0 -
1.2 4.5
0.6 -
0.4 3.8
-
-
1.2 4.8
_
72.1
71.6
_
_
_
_
72.1
73-6
73-3
72.2
-
71.1
-
69.3
-
-
75.3
_
1.1
1.2
_
_
_
_
1.2
_
1.1
1.2
1.3
-
1.2
-
1.2
-
-
1.3
_
11.3
13.0
_
_
-
_
11.9
12.3
12.1
12.1)
-
13-1
-
19.3
-
-
12.5
•
Btu
as
received
11,050
10,900
11,010
10,550
10.&ZO
11,030
11,000
10,960
10,710
10,880
10,890
11,180
11,120
10,860
10,450
9,740
10,230
9,270
8,863
10,170
10,330
10,290
Ash
softening Free
Stu tenpera- swelling
dry ture,P° index
12,760
_ — _
12,460
12,630
_ _
_ _
_ _
_ _
12,410
12,950
12,840
12,710
12,580
12,280
12,270
11,690
11,477
-
_ -
12,910
Hardgrove
grindability
index
-
_
_
_
_
_
_
_
_
_
_
-
-
-
-
-
-
-
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
County
Coal
field
or
town
Mine
Proximate
analysis , %
I
Date fa
of ra
analy- -g
Name sis Seam £
Volatile
a
o
•H
t
Ultimate
analysis, t
EQ
C S>
1 p O P
i I 1 1
1 Btu
x as
o received
Ash
softening Free
Btu tempera- swelling
dry ture,F° index
Hardgrove
grindability
index
MONTANA (continued)
Mjssel-
Shell
11
It
2 mi E
Mussel-
Shell
it
Roundup
Black
Diamond
Grants
Prospect
Mary Mc-
Ceary &
1967
1967
1967
20.6
28.7
29.1
31.8
35.9
35.9
59.4
55-2
55.0
5.8
8.9
9.1
2.0 1.5 71-0 1.2
0.8 - -
0.5 - -
12.5 10,150
7,210
7,210
12,770
10,150
10,150
-
~
-
Anne Oker
it
n
n
n
n
n
IT
Park
ti
n
n
n
n
n
"
it
Bull
MDuntain
1 mi NW
Painted
Rock
Meyers-
burg
Livings-
ton
Chestnut
ti
Prospect
Keen No. 2
n
n
Kuchts
Prospect
Surface
Prospect
Local
Sholz
Potters
Livings-
ton
Hoffman
it
it
n
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
19.0
17-3
20.1
28.6
18.1
18.1
11.6
2ii
.4
6.2
12.5
10.4
12.1
13.2
31-5
31.9
35-3
38-9
31.8
33.2
36.0
32.6
35-5
32.0
42.1
38.5
55-9
55.6
56.5
51.1
54.0
61.7
45.6
39.1
15.2
33.5
48.2
42.5
9.6
9-5
8.2
10.0
11.2
5-1
18.4
28.0
19-3
34-5
9-7
19.0
1.2 - -
1.0 - -
1.0 - -
0.9 - -
2.0 1.8 65.8 1.0
1.1 1.2 73-9 0.9
1.3 - -
0.7 1.3 57.1 0.9
0.6 - -
0.5 - -
0.7 4.9 71.1 1.1
0.7 4.5 60.6 1.0
9,610
9,920
9,750
7,110
15-3 9,320
11.8 10,120
10,010
12 337
8.6 9,790
— ~
12.3 10,950
11.2 9,520
11,870
12,000
12,200
9,960
11,130
12,730
11,330
10,150
_ — —
12,500
10,960
—
~
~
-
-
~
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
County
Coal
Held
or
town
Mine
Name
Proxljnate
analysis, %
I
Date £
°f tn
analy- >H
sis Seam £
Volatile
8
O
1
S
1
MONTANA
Park
n
n
it
n
n
n
n
Phillips
n
if
Poodera.
Powder
River
n
n
n
n
n
n
n
n
n
Electric
Chluney
Rack
Aldrldge
n
n
n
n
Horr
Malta
"
Zortman
Valier
Mountain
House
Maxey
South
Aldrldge
n
n
ti
Poster
Newton
Ruby
Gulch
Spencer
Indian
Feser.
A.G.
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
196?
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
11.7
16.3
4.0
5.2
1-9
17.5
3-0
4.2
20.8
24.1
H.9
6.6
29.6
31.3
30.6
28.4
30.1
30.2
31.6
31-5
30-5
33.1
41.2
36.0
23-5
37-3
20.2
23-5
30.5
28.6
35.5
35.2
37.8
43.2
40.0
38.1
40.3
38-9
38.0
38.2
39-1
39-4
39-4
40.5
46.9
47.9
61.8
42.3
55.8
54.8
58.0
51.1
38.9
30.1
47.7
41.9
47.7
51-3
47.7
44.1
53-1
48.9
51.8
50.0
53.?
49.5
11.9
16.1
14.8
20.5
24.0
21.7
11.4
20.4
25.6
34.7
14.5
14.9
12.3
10.6
12.1
16.9
8.9
12.9
9-1
10.6
7.4
10.0
3
Ultimate
analysis > *
ttydrogen
i
Nitrogen
!
Btu
as
received
Ash
softening Free
Btu tempera- swelling
dry ture.F0 index
Hardgrove
grindability
index
(continued)
0.4
0.5
0.6
0.6
0.4
6.6
0.9
1.4
1.8
0.8
0.7
3-3
2.3
0.6
0.5
0.5
0.3
1.1
0.3
0.5
0.3
0.6
4.6
U.O
4.3
4.2
4.2
4.9
4.5
_
_
2.5
4.7
4.4
4.6
4.5
4.4
4.0
4.2
4.0
4-3
3-7
4.2
69-3
63.9
73.5
65.6
66.7
75.9
66.9
..
_
58.8
65.0
65-8
66.2
65.0
61.1
68.0
64.6
67.5
65.7
68. 7
66.2
1.0
1.0
1.2
_
0.9
1.1
1.2
1.0
_
_
1.0
1.2
1.1
1.0
1.0
1.0
1.0
1.0
1.0
1.0
1.1
1.1
12.7
14.5
5-7
4.8
5.7
5-7
5-8
_
_
22.5
10.9
14.2
17.3
17.0
16.0
17-7
16.2
18.0
17-8
18.8
17.9
10,760
9,250
12,764
10,687
11,320
9,875
13,286
11,414
6,860
5,200
-
10,930
7,840
7,550
7,500
7,300
7,860
7,570
7,630
7,540
7,820
7,380
12,190
11,050
13,289
11,273
11,536
11,970
13,700
11,921
8,650
6,850
11,690
11,140
10,990
10,810
10,280
11,240
10,860
11,150
11,010
11,240
11,040
—
_
_
_
_
_
_
-
_
_
—
-
_
-
-
-
-
-
-
-
-
-
-------
Table 0-1 (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
uo
County
Powder
River
"
Coal
field
or
town
CoalwDod
n
n
Mine
Proximate
analysis , '•
Date £
of $
m
analy- -H
Name sis seam S
Ash
Creek
North
Star
Cool
1967
1967
1967
35.2
33-9
30.0
rH
•H
1
47. 2
13-1
41.9
&
O
1
I
1 3
Ultimate
analysis, I
1
1
c
1
P
g
MONTANA (continued)
46.6 6.2 0.5 - - -
47.7 9.2 0.4 - - - -
51.1
7.0 0.7
4.5
69.4
l.l
17.3
Btu
as
received
6,930
7,300
8,160
Ash
softening Free
Btu tempera- swelling
dry ture,F° index
10,700
11,040
11,660
Hardgrove
grindability
index
-
-
Creek Strirt
n
n
n
«
n
n
n
it
n
n
i
i
i
i
i
Praire
11
Otter
Creek
Broadus
n
it
n
tt
Cache
Creek
Broadus
n
n
it
tt
ti
tl
ti
Terry
Lignite
Fallen
Core Samp. 1967
Curran &
Marengo
Two Trees
Peerless
«
V.Stablo
Prospect
Core
Sample
Black
Diamond
Superior
Core
Sainple
H
H
H
it
Strip
Pit
Glfford
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
26.6
30.8
19-5
33.9
34.6
29.0
32.0
32.3
33-5
28.2
30.4
27.2
28.3
27-9
27.9
28.1
33.5
40.3
38.8
44.4
40.2
40.4
44.1
43.4
44.0
42.5
42.7
40.7
41.6
41.3
43.0
41.1
-.
38.8
52.6
50.0
46.7
50.1
51.1
11.4
47.8
46.4
48.5
51.0
53-1
50.4
52.7
50.0
49.4
_
44.2
7.1 0.3
11.2 0.4
8.9 0.3
9-7 0.3
8.5 0.4
0.5 -
8.8 0.3
9.6 0.4
9.0 0.6
6.3 1-1
6.2 1.2
8.0 0.8
6.0 0.6
7.0 1.4
9.5 0.8
22.1 0.4
17.0 1.0
1.7
4-3
4.3
4.4
-
1.7
-
iTs
4.7
4.6
4.5
4.8
4.5
_
-
70.8
65.0
63.8
66.6
-
66.7
-
69.4
70.1
68.3
70.2
69.2
67.3
-
-
1.1
1.0
1.2
1.0
-
1.1
-
1.3
1.2
1.3
1.3
1.3
1.2
-
-
16.0
18.1
21.5
19.1
-
18.4
-
17.1
16.6
17.0
17.4
16.3
16.7
-
-
8,710
7,560
8,490
7,240
7,220
6,390
7,650
7,380
7,290
8,590
8,390
8,530
8,620
8,680
8,280
5,310
-
11,910
10,920
10,540
10,650
11,040
9,010
11,250
10,900
10,970
11,970
12,060
11,720
12,020
12,030
11,490
8,780
— — —
—
—
-
™
—
~
-
—
-
-
~
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
County
Pralre
Ravalli
Richland
n
n
n
n
Roosevelt
n
n
Resets*!
fl
n
If
tr
Coal
field
or
town
Eallon
Darby
n
Savage
Culbert-
son
MDrriak
Culbert-
son
it
it
"
Bainville
Eroid
tl
Castle
Rock
Colstrip
n
n
n
Mine
Proximate
analysis, 1
s
Date fj
of S
analy- -H
Name sis Seam £
Nichol-
son
Knife
River
Coal Co.
Pust
Lane
Elurio
Savage
Butter-
field
Open Pit
Bruegger
n
Desnpsey
Prospect
Red Bank
Prospect
Astrope
Brinkard
Prospect
N.W. Im-
proviflsnt
n
Eureka
Colstrip
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
28.5
30.6
38.6
38.3
36.5
38.8
37.9
37-5
41.6
43.2
32.6
38.9
35.3
42.8
37.7
40.7
26.6
24.6
24.3
23-1
20.6
Volatile
40.0
52.2
40.8
41.1
42.4
41.6
40.9
42.9
46.4
38.8
40.7
44.5
49.2
45.0
41.5
42.5
39-4
37.4
37.0
38.8
-
8
1
e
1
Sulfur
Ultimate
analysis, %
Hydrogen
!
Nitrogen
1
Btu
as
received
Ash
softening Free
Btu terrpera- swelling
dry ture ,F° Index
Hardgrove
grlrriability
Index
MDHTANA (continued)
49.4 i(X5 l.'o -" _'"_--
30.0 17.8 1.0-----
47.8
49.2
47.2
48.6
48.9
47.4
45.6
51.0
45.8
45-3
38.8
46.9
49.6
47.0
51.4
52.3
53.4
54.0
-
11.4
9.7
10.4
9.8
10.2
9.7
7.0
10.2
13-5
10.2
12.0
8.1
8.9
10.5
9-2
10.3
9.6
7-2
-
1.5
0.8
1.4
0.8
0.8
0.5
0.6
0-5
1.9
1.2
1.8
3.4
1.2
1.2
2.5
0.6
1.2
0.9
-
4.0
-
-
-
-
4.1
3.8
4.2
4.2
3-6
4.3
4.5
4.4
-
-
3-8
4.9
-
64.4
-
-
-
-
63.8
61.7
-
59-9
59.9
54.1
63.2
63.7
61.7
-
-
70.8
71.4
-
1.0
-
-
-
-
1.0
1.3
-
1.0
1.2
1.3
1.1
1.1
1.2
-
-
1.1
1.0
-
17-7
-
-
-
—
20.9
25-6
-
19.5
22.3
27.2
22.8
20.6
21.0
-
-
13-5
14.6
-
6,880
-
11,250
6,710
6,710
6,580
5,730
6,000
6,710
6,010
5,400
6,110
6,700
6,150
8,080
8,850
9,230
9,500
9,170
11,140
_ _ _
7,050
10,880
10,730 2,500
10,530
9,820
10,566
9,960
9,840
8,360
10,680
10,760
10,380
11,010
11, 7^0
12, WO
12,350
— - -
-
-
-
-
—
-
-
-
-
-
-
-
-
-
~
-
-
~
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
VJl
County
Rosebud
ti
it
n
K
it
n
n
tl
n
n
fi
fi
ti
M
ft
rt
n
tt
n
tf
tt
tt
tt
ti
Coal
field
or
town
Colstrip
«
Tt
n
tt
n
tt
n
tt
tt
it
n
tt
n
n
it
rt
ti
tt
it
tt
rt
M
tt
fl
tl
Lee
Forsyth
ii
ti
Mine
Date |
of S
analy- g
Mams sis Seam S
Colstrip
fi
tt
n
tt
tt
n
n
n
tt
n
Tt
n
IT
Tt
Tt
It
It
IT
II
II
II
It
It
II
II
Prospect
Wright
Harare
McKay
Alderson
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
23-5
22.3
21.9
25-8
23-9
21.6
23.3
21.1
23-9
21.1
25-5
23.8
21.1
25.2
21.1
22.3
21.0
26.2
21.1
21.5
26.1
21.6
22.8
26.5
25.6
25.6
23-6
23.7
16.6
23.9
28.7
Proximate
analysis , %
4) Si
rH O
T-t
4J T3
" « C
O "H tD
£ fr. <*
MONTANA
37-2
11.1
37.1
37.1
37-7
38.0
36.8
37.6
39-3
30.1
37-5
26.2
37.7
53-0
17-7
53.0
53-8
51.2
51.9
51.1
52.6
19.8
51.8
16.8
30.2
52.9
9.8
10.9
9.6
9-8
U.I
10.1
8.8
9.8
10.9
15.1
15.7
13.6
9.1
Sulfur
Ultimate
analysis ,
£ °
*9 3
5? 8
*
g ^ Btu
S x as
£ 8 received
(continued)
1.1
1.2
1.0
0.8
1.2
1.1
1.1
1.2
1.0
2.0
0.8
0.7
0.8
1.5 69.7
3.8 62.9
1.7 70.6
1.5 69.9
1.9 68.7
5.0 68.5
1.7 70.1
1.8 69.1
1.0 13-9
1.1 20.1
1.0 13.1
1.1 13-9
1.1 13-0
1.1 11.2
1.0 11.3
1.0 11. 1
9,090
9,290
6,870
8,960
7,910
9,070
9,360
8,920
9,110
9,090
8,910
8,960
8,960
9,010
9,050
9,330
9,160
8,780
9,080
8,970
8,860
8,980
9,130
8,850
:8,920
8,760
8,360
8,080
5,130
9,160
8,630
Ash
softening Free
Btu tenpera- swelling
dry ture.F0 Index
11,910
10,390
11,960
11,880
11,910
12,010
11,980 - •
11,770
10,950
10,590
6,510
12,030
Hardgrove
grinclabllity
Index
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
County
Coal
field
or
town
Mine
Name
Proximate
analysis , 1
I
Date
of
analy-
sis
g
-p
to
•H
Seam £
a
S
i—t
8
o
•g
1-i
pt.
<§
.C rH
< CO
Ultimate
analysis,
1
g §
3? 8
«
£
s
VH
z
1)
1
Btu
as
received
Ash
softening Free Hardgrove
Btu tempera- swelling grindabil'tv
dry ture.F0 index index
MONTANA (continued)
Rosebud
n
n
Sheridan
it
n
n
tt
tt
Still-
water
n
n
ii
tt
Toole
Ashland
n
"
Medicine
Lake
it
n
Plenty-
wood
n
Antelope
Medicine
Lake
Plenty-
wood
n
teleview
Dean
n
"
Kye
Shelby
Holt
Brewster
Arnold
Kendrlck
Ted Young
Belgon
Jones
Acme
Lee
n
Richard-
son
Coalridge
Pierce
Bros.
Pierce
Ranous
Albert-
son
Garoutt
"
Loffer
W. Butte
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
27-3
27-3
28.9
39-3
11.3
11.6
36.7
35.7
37-2
29.1
10.1
11.3
31.3
36.6
12.5
7-0
7.5
6.9
6.7
7.2
_
39.8
11.5
39.8
13.7
15.7
16.1
10.9
12.0
11.8
11.1
12.1
15.0
36.5
35-5
32.3
11.2
36.9
31-7
36.6
_
53-9
53-9
50.7
18.1
11.8
11.2
17.1
19.1
17.8
16.3
16.1
12.7
17-9
11.3
17.6
51.6
17.1
12.7
51.5
_ _
6.3 0.8
1.6 0.1
9-5 0.9
8.2 0.6
9-5 0.7
18.1 1.0
11.7 2.7
8.9 0.6
10.1 0.1
12.6 0.7
11.5 0.7
12.3 1-0
15.6 0.1
20.2 0.7
20.1 0.5
7.2 1.1
16.0 0.7
17.6 0.6
9-0 1.9
_ _
1.7 70.7
1.3 68.1
1.2 62.3
1.3 63.3
3.7 57-1
3-8 59-6
1.2 63.1
1.1 65.9
-
1.1 59.0
_ _
_ _
3-5 60.5
_ _
-
5-3 71.7
1-7 67.5
1.6 65.9
1.7 72.8
_
1.1
1.2
1.1
1.1
1.1
1.6
1.2
1.1
-
1.0
_
_
0.8
_
-
1.5
1.2
1.2
1.5
—
16.1
21.0
22.0
22.5
27.6
15.6
16.8
19.1
22.6
_
_
19.2
_
-
10.2
9-2
10.1
10.1
9,020
8,850
8,231
6,280
6,200
5,280
6,110
6,750
6,850
7,500
5,830
5,870
6,760
6,110
8,350
10,130
12,180
11,010
10,000
11,771
- - -
12,170 - - _
11,570 -
10,350 -
10,066 -
9,010 -
9,710 -
10,190 - - -
10,910 -
10,580 -
9,780 -
10,000 -
10,200 -
9,680 -
9,450 -
10,890 -
13,160 -
11,850 -
11,450 -
12,683 -
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
County
Treasure
Valley
n
n
Wheatland
n
M
Wibaux
tt
Yellow-
stone
ft
"
n
n
n
tt
it
Coal
field
or
town
Big Horn
Ophelm
n
E. Scobey
Harlotown
"
n
28 ml NE
Hunt ley
n
Bull
Mountain
Buokey
11
Hunt ley
Wolf-
spring
20 mi NE
Pine Ridge
Mine
Name
Prospect
Daws on
Baldwin
Bros.
Fisher
Prospect
Outcrop
Prospect
Pepllnskl
Stair
Prospect
"
Outcrop
Prospect
11
n
Outcrop
H
Proximate
•analysis, '•
Date
of
analy-
sis Seam
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
1967
4J
•H
£
19.8
45.9
42.7
41.3
10.4
25-3
29.4
41.0
37-9
17.4
18.6
29-7
24.6
17.4
21.6
15-1
-
CD
t— (
.H
>H
^
38.2
41.5
41.1
39.7
24.9
31.4
38.9
42.0
42.6
37.7
36.4
41.3
43.6
37.8
38.8
19-3
-
§
V,
%
e
43.9
45.4
43.7
45.5
35.8
19.1
44.3
44.7
41.9
58.2
57-3
52.9
37-0
54.6
54.8
25-3
-
si
to
MONTANA
17.9
13.1
15.2
14.9
39.4
19-5
16.4
13.3
15.5
4.0
6.3
5.8
19-4
7-7
6.3
55.4
-
Ultimate
H 1 g
rH -D |a
£ fc o
(continued)
1.9
0.5 3.9 61.2
1.0 3-9 60.2
0.5 - -
0.6 - -
0.6 - -
0.4 - -
1.6 - -
1.6 - -
0.4 - -
1.0
0.5 - -
0.5 2.8 54.9
0.6 4.2 71.5
0.9
0.2 .-
_ _ _
E
t£ C
o <£ Btu
£ & as
2 o received
8,580
1.1 20.2 5,470
1.0 18.7 5,640
5,634
7 as
6)383
6,374
6,050
6,140
10,280
9,892
7,100
0.9 21.5 6,208
1.1 14.9 10,121
9,016
3,850
_
Ash
softening Free
Btu tenpera- swelling
dry ture,F° index
10,700
10,000
9,830
9,598
8,048
8,540
9,022
10,240
9,890
12,451
12,160
10,170
8,233
12,262
12,271
4,540
- - -
Hardgrove
erind&bilitv
IjTdex
-
_
-
-
_
-
-
_
-
-
-
-
-
-
-
—
NEW MEXICO47*"8,101
McKinley
n
Gallup
H
McKinley
Sundance
Black
Diamond
15.0
12.5
44.0
45.1
47.7
48.9
8.3
6.0
.6
.8 - -
10,790
11,550
12,680 2,340
13,190 2,460
51
-------
Table G-l (continued).
WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
OO
County
tfcKinley
tl
ft
Colfax
n
Santa Fe
n
n
SOCOTTO
McKLnley
n
Coal
field
or
town
Gallup
n
n
Cranpolnt
Standing
Rook
Raton
n
Cook &
White
n
Miller
Gulch
Unknown
Gallup
n
Mine
Proximate
analysis , %
§
r»
Date
of
snaly-
Nane sis Seam
Sundance
n
n
n
n
n
n
n
n
Roberts
n
Brilliant
Van Houten
Jones
Lanfc
Miller
Gulch
Law
Prospect
Sundance
McKinley
Black
Diamond
n
n
it
n
n
TI
n
ti
Black
Diamond
Uncor-
pelated
jj
[a
•H
£
12.6
11.8
11.2
12.8
9-9
11-7
10.5
13.0
10.2
9.5
11.6
1.9
2.0
2-9
2.4
2.2
2-5
11.7
13-7
3
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
County
Coif ax
If
n
it
tt
tt
it
it
Tt
tt
tt
ft
It
M
II
«
t|
11
McKinley
n
it
it
it
n
Coal
field
or
town
Dawson
n
n
ti
it
tt
tt
Koehler
tt
it
n
if
T|
tt
tt
tt
tt
Gallup
H
tt
tt
Mine
Name
Brilliant
KL-N O
no. c.
ti
Dawson
No. 6
n
ti
Koehler
Nos. 18,2
n
ti
it
it
it
n
11
ti
it
Mutual
Navajo
No. 5
it
it
11
11
n
Proximate
analysis, %
1
Date
of
analy-
sis Seam
1947
1917
1949
1948
1948
1917
1950
1918
1950
1947
1917
1917
1919
1950
1917
1919
1918
1950
1950
1918
1919
1950
Raton
n
tt
tt
ti
tt
tt
it
tt
n
it
tt
ti
ti
ti
n
Aztec
Upper Mesa
Verde
n
it
n
n
m
£
1.0
1.0
1.8
1.6
1.9
1.8
1.9
1.8
1.9
2.0
2.0
2.0
3.1
2.2
1.6
3.6
J* w
2.5
7.8
5-9
8.3
10.7
8.3
10.3
11.2
4)
1-1
•H
rH
£
33.8
33;7
38.5
38.8
39-0
35.8
35-3
35-7
36.6
38.6
38.2
37.9
36.9
38.0
36.9
36-3
42.7
39-8
41.3
42.1
39.8
41.1
41.9
3
o
•p
1
£
1
Ultimate
analysis, *
«— * *9 ja ^
>> as
8 received
Ash
softening Free
Btu tempera- swelling
dry ture,F° index
Hardgrove
grindabillty
index
NEW MEXICO (continued)
49.8 16.4 0.7-----
50.9
48.8
48.4
17.3
18.0
48.4
47.4
48.5
49-9
51.4
50.8
49.1
19-5
48.7
48.4
44.5
49.9
52.7
51.6
50.2
18.1
48.5
47.8
15-2
12.5
13-1
13-9
13.0
15.8
17-3
15.8
13-5
10.0
n.o
13.0
13.6
13-3
14.7
19.2
7.1
7.5
7-1
7.7
12.1
10.4
10.3
.7 5.0 71.2 0.9
.6 — - -
.6 - -
.7 - -
.7 - -
.6 - -
.6 - -
.7 - -
.7
.8 5-3 75.0 1.4
'.6 - -
.7 - -
.8 - -
.6 - -
.7 - -
0.5 - -
.5
'.6
'.6 - -
.5 - -
12,460
7.0 12,680
12,990
12,950
12,750
12,950
12,300
12,100
12,250
12,660
7.5 13,240
13,050
12,600
12,660
12,750
12,240
11,620
- 11,960
12,210
11,980
11,560
11,260
11,190
11,140
12,590
12,810
13,230
13,160
13,000
13,190
12,530
12,320
12,490
12,920
13,520
13,330
13,010
12,950
12,970
12,690
11,910
12,970
12,970
13,060
12,950
12,280
12,480
12,550
2,910
2,910
-
— —
2,890
2,870
2,910
2,910
2,910
2,910
2,910
-
2,570
2,480
2,500
-
-
-
—
-
-
—
~
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
County
Coal
field
or
town
Mine
Proximate
analysis, *
g
Date £
Of 4i
analy- 5
Name si3 Seam &
r-t
1
§
£
1
Ultimate
analysis ,
1 1 1
%
g | Btu
S & as
z o received
Ash
softening Free
Btu tenpera- swelling
dry ture,F° index
Hardgrove
grindability
Index
NEW MEXICO (continued)
McKinley
n
n
n
n
Rio Arrlba
Sandoual
Santa Pe
n
Bowman
n
Mercer
"
Ward
Burke
Mentnore
n
n
n
n
Lumber-ton
n
n
n
Cuba
Madrid
n
Gascoyne
Tf
Beulah
11
Columbus
Larson
Mentncre
n
H
n
Araargo
N
n
Black
Kose-
Jones
n
Peerless
East Pit
Peerless
West Pit
1949
1950
1948
1950
1950
1949
1950
1949
1950
1948
1950
1950
Beulah
Knife River
"
Velva
Kincaid
Mesa Verde 9.4
" 7.2
" 9.1
" 8.8
9.6
2.8
2.5
2.7
3-7
17.1
Cooke- 1.3
White
2.0
42.1
42.7
36.4
35.6
Voltaire 34.0
34.5
40.6
46.0
H5.2
45.4
40.8
41.4
37-7
38.2
40.3
33-9
34.4
39.7
45.0
40.5
40.1
24.0
40.7
50.0
44.9
47.2
47.0
45.0
52.2
52.9
47.2
48.3
50.3
54.3
53.1
NORffl
48.2
45.2
48.5
47.1
31.5
48.1
9.4
9.1
7.4
7.8
9.6
7.0
5.7
15-1
13.5
9.4
11.8
12.5
-5 - -
!s I I
'.6 - -
2.0
.6 - -
1.4
1.3
2.6
1.0
1.0
11,460
11,960
11,900
11,930
11,590
13,400
13,780
- 12,130
12,330
10,040
12,840
- 12,690
12,650
12,880
13,090
13,080
12,820
13,790
14,130
12,470
12,800
12,100
13,000
1P.940
*~
-
-
-
DAKOTA117, "8
12.1
9.8
11.0
12.5
7-5
11.2
1.4
1.7
1.5 -
1.8
0.2 6.4 40.4
.8
6,270
6,280
6,880
6,830
0.7 44.8 7,090
7.160
10,820 2,250
10,960 2,480
10,810 2,360
10,610 2,180
-
lo.qJio ?. inn
54
46
58
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
CO
County
Coal
field
or
town
Mine
Proximate
analysis , %
I
Date |
of ra
analy- -g
Mams sis Seam E
o
rH
•H
a
O
1
•H
(fa
1
Ultimate
analysis, %
, 1 c "
26
| | Btu
z & received
Ash
softening Free
3tu tempera- swelling
dry ture,F° index
Hardgrove
grindability
Index
1 ' NORM -DAKOTA (continued)
Burke
n
ii
n
tl
n
Mercer
it
n
11
„
„
Burke
Divide
n
tfercer
Ward
Larson
n
n
n
n
Beulah
n
it
it
n
Hazen
Zap
Columbus
Noonan
„
Beulah
Zap
Velva
McHenry
County
Baukol
Noonan
n
it
n
it
Beulah
ii
n
Beulah
South
Dakota
Star
Indian
Head
Kincaid
Baukol-
Noonan
it
Beulah
Knife River
Indian Head
Velva
33.1
33.1
33.1
33-2
31.2
31.9
36.4
36.5
35-9
35.6
35.6
34.0
33-2
34.4
33-8
33-8
34.8
33.3
38.6
40.3
41.0
41.5
10.3
39.6
38.2
11.6
11.3
11.5
39.1
40.9
42.1
10.9
10.1
11.0
11.0
44.0
42.8
43.2
49.8
49-9
49.8
19.3
50.1
17.3
51.0
50.1
49.6
50.0
49.7
48.7
47.1
46.8
49.2
48.7
48.8
48.8
48.9
9-9
9-1
8.7
10.4
10.0
14.5
7.4
8.3
8.9
10.9
9-4
8.9
11.7
13.1
9.8
10.3
10.2
8.4
7-9
.5 - -
.4
.6 - -
'.6
.8 - -
.7
.9
•9 - -
.8 - -
.9
.9 - -
.8 - -
1.0
.6
.6 - -
1.0
.6 - -
.4 - -
7,150
7,530
7,650
7,400
7,310
6,920
7,050
6,980
6,990
6,850
6,990
. - - 7,280
7,200
7,070
7,170
7,130
7,080
7,190
6,730
11,170
11,320
11,500
11,100
11,120
10,640
11,080
10,990
10,900
10,650
10,850
11,050
10,800
10,800
11,300
11,240
10,880
11,210
10,970
2,260
2,130
2,190
2,120
2,170
2,080
2,170
2,160
2,470
2,180
2,430
2,340
2,110
2,170
2,180
2,200
2,390
-
2,570
38
-
62
51
-
-
—
-
—
~
—
"
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
County
Coal
field
or
town
Mine
Proximate
analysis, ?
I
Date £
of 3
analy- -S
Mare sis seam s
Volatile
i
1
•H
fc.
1
Ultimate
analysis, %
1 £ 1
c
tc
oj Pi--]
6C jC-1
S & as
z o received
Ash
softening Eree
Btu tetniera- swelling
dry ture,F° index
Hardgrove
grindabiUty
index
NQRIH DAKOTA (continued)
Ward
Adam's
Jr
CO
PO Bownan
Burke
p
Mercer
Ward
If
tt
tl
Burke
tl
11
ft
tl
Velva
McBenry
County
Haynes
n
Gascoyne
Larson
n
Beulah
Sawyer
n
it
Velva
McHenry
County
Columbus
n
n
IT
larson
Velva
Arrowhead
n
Gascoyne-
Peerless
Baukol
Ifoonan
it
Beulah
Valley
n
n
Velva
Klncaid
u
n
n
Baukol
Noonan
unoor- 37.3
related
32.3
31.8
41.5
" 32.8
32.3
34.7
39.3
" 39.1
40.1
37.6
35.6
34.9
33.0
34.7
33-3
44.2
39.9
40.3
43.8
41.4
41.0
42.0
42.9
43.2
40.7
43.1
39.3
39.8
39.1
36.5
40.4
16.9
13.7
10.6
11.1
47.9
19.2
18.7
51.0
19.6
50.9
48.5
51.3
49.7
48.0
43.7
49-3
8.9
16.1
19.1
11.8
10.7
9.8
9.3
6.1
7.2
8.1
7.8
9.4
10.5
12.9
1918
10.3
• 5 - -
1.7
2.1
1.6
.5 - -
.4 - -
.8 - -
.3 - -
.3 - -
.3 - -
.2 - -
.6 - -
.6 - -
.8
-9
.if - -
6,700
7,010
6,970
6,300
7,370
7,600
7,170
6,640
5,690
6,410
6,750
7,150
7,180
7,160
6,430
7,450
10,690
10,350
10,220
10,770
10,970
11,220
10,980
10,980
10,980
10,780
10,820
11,110
11,020
10,680
9,860
11,180
2,380
2,080
2,090
2,210
2,100
2,080
2,370
2,580
2,540
2,470
2,500
2,040
2,050
2,060
2,050
2,080
-
62
46
-
-
58
_
—
^ .
_
_
_
-
32.6 40.3 49-3 10.4 .4
7,460 11,090 2,090
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
CO
LO
Mine
County
Coal
field
or
town
Mane
Date
of
analy-
sis seam
G)
3
i
Proximate
analysis, *
I
0)
cH
3
o
e
1
Ultimate
analyeis, <
g
§ 0
3 I 1
c
O K. Btu
4j >i as
2 o received
Btu
dry
Ash
softening
tempera—
ture.F01
Free Hardgrove
swelling grindability
Index Index
NORTH DAKOTA (continued)
Mercer
n
n
n
n
Ward
n
tt
IT
Adams
n
ft
n
n
Bowman
Hazen
tt
Zap
n
Velva
McHenry
County
n
it
n
Haynes
n
tt
n
Haynes
Dakota
H
Indian
n
Velva
„
n
n
Arrow-
head
n
Pearl
Butte
n
Bowman
Twin
Star
Head
1917
1917
1917
1917
1917
1916
36.1
31.6
35-3
31.0
31.8
38.2
38.5
31-5
36.2
35.1
35.1
31.9
36.5
35.5
18.3
12.3
12.7
10.8
11.8
10.1
13-3
13.1
13-5
12.0
12.2
15.0
12.5
11.2
15.1
16.5
18.6
18.8
19.1
16.3
18.0
50.2
19.5
19.6
19.5
11.5
11.2
37.8
11.6
11.9
13.0
9.1
8.5
10.1
11.9
U.6
6.5
6.8
6.9
8.5
13-3
13.8
19.7
11.2
13.0
10.5
1.0
.8 - -
.9 - -
1.7
1.2
.1
.1 - -
.3
.1
1.6 1.3 63-3
2.5
2.7
1.7 1.7 65.6
2.1
1.7 1.5 63.9
7,090
7,250
7,070
7,110
7,010
6,850
6,780
7,010
6,910
0.8 16.7 6,960
7,000
6,110
0.9 15-9 7,230
7,190
0.9 18.5 5,660
11,100
11,100
10,920
10,780
10,800
11,090
11,020
11,270
10,880
10,780
10,810
9,900
11,390
11,110
10,910
2,170
2,380
2,050
2,130
2,100
2,510
2,570
2,500
2,170
2,190
2,190
2,150
2,310
2,290
2,170
-
- -
51
— —
31
_ _
- -
- -
-
— —
-
-
Buttes
Burke
It
tt
tt
Columbus
n
ti
Klncald
n
tt
it
1916
1916
1916
1916
36.1
35.7
31.1
31.1
10.6
12.2
10.1
38.1
50.6
18.7
17-2
45.1
8.8
9.1
12.7
16.8
0.6 1.1 66.1
0.6 - -
0.7
0.6 - -
1.0 18.8 7,180
7,210
7,070
6,710
11,230
11,220
10,780
10,270
2,190
2,130
2,110
2,090
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
CO
County
Coal
field
or
town
Mine
Proximate
analysis , ^
I
Date
of
analy-
Nane sis Seam
§
s
£
1
1
£
C r-t
Ultimate
analysis, %
!
i I
I
Btu
as
received
Ash
softening Free
Btu tempera- swelling
dry ture,F° index
Hardgrove
grtndability
index
WORTH DAKOTA (continued)
Burleigi
It
Divide
tl
n
M'Lean
n
William
n
n
n
n
n
n
n
n
Coshocton
n
Perry
n
Wilton
n
Noonan
n
n
Garrison
n
Williston
n
n
n
n
n
n
n
n
Coshocton
n
Coming
New Lex-
ington
Baokman
Bckland
Bautol
Noonan
n
Ouster
n
Avoca
n
n
Holland
Square
Deal
n
n
Willlstcn
View
IT
Broken
Arow
n
1917
1917
1916 Noonan
1916 "
1916 "
1917
1917
1916
1916
1916
1916
1916
1916
1916
1916
1916
1916
1973 Middle
1973 Kittanlng
No. 6
Congo "
Sunny Hill "
ft*ep. plant
10.1
39.9
31-3
35.1
35-5
39.5
39-5
13.0
13.2
12.6
13.2
12.8
11.8
12.0
38.6
12.1
10.8
6.2
6.1
8.8
8.0
15.8
11.7
11.6
12.1
11.2
13-9
15.1
13.5
13-5
11.7
38-9
13.8
13.6
11.8
39.6
11.6
13-7
17.6
15.9
36.9
11.3
15.8
13.2
50.5
18.1
1618
18.2
18.6
17.8
17.9
11.9
11.7
17-9
18.8
17.0
39.1
18.1
16.6
16.6
12.8
16.3
15.9
8.1 l.o
12.1 1.3
7.9 0.6
9.8 0.7
12.0 1.0
7.9 0.6
6.3 0.6
8.7 1.0
8.6 1.0
13.1 1.0
16.1 0.8
8.3 0.7
7.6 0.9
11.2 1.1
21.0 1.5
7.3 0.7
9.7 0.8
5.8 1.0
2.7 -
16.8 0.9
12.8 2.7
1-5
1.1
1.1
_
1.6
1.6
lie
1.6
1.1
1-7
-
-
-
1.5
65.6 0.9
63.6 1.0
66.8 1.2
_ _
66.6 1.1
65.8 1.0
65.3 1-2
66.2 1.2
61.0 1.1
66.3 1.2
-
-
-
66.6 1.5
19.6
17-6
19.1
_
20.8
19.0
19.9
19.5
18.2
19.8
-
-
-
9-7
6,660
6,180
6,130
7,180
7,010
6,700
6,810
6,160
6,380
6,070
5,780
6,380
6,550
6,290
5,900
6,570
6,510
12,790
11,110
10,810
11,110
11,110
10,790
11,300
11,120
10,920
11,060
11,250
11,310
11,220
10,580
10,180
11,160
11,270
10,810
9,620
11,100
10,990
13,610
12,110
11,850
12,110
2,510
2,390
2,310
2,230
2,180
2,510
2,580
1,260
2,190
2,080
2,100
2,320
2,380
2,090
2,070
2,120
2,110
2,010
2,360
2,790
2,360
-
_
-
-
-
-
_
-
-
.
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
oo
County
Ward
Tt
n
n
n
n
"
"
n
n
n
it
fi
ii
n
it
it
it
Williams
n
it
tt
tt
it
Coal
field
or
town
Sawyer
n
Tt
if
n
tt
tt
n
Velua
tf
11
It
11
Tlaga
11
11
It
11
Wheelock
Mine
ffeme
Miller
Strip
Tt
tt
n
n
Vlx
tt
n
n
West Side
11
tt
n
Velua
tf
n
»
M & M
ii
ti
n
tt
Cedar
Coulee
# 2
Proximate
analysis, ?
1
Date
of
analy-
sis Seam
1946
1946
1946
19*6
1946
1946 Coteau
1946 "
1946 "
1946 "
1946 "
1946 "
1946 "
1946 "
1946 "
1946 "
1946 "
1946 "
1973
1946
1946
1946
1946
1946
1946
a
-P
vl
£
39-0
38.7
38.9
40.3
40.8
39.8
38.7
38.6
38.4
38.5
38.2
38-3
39-2
39-1
39.1
38.6
38.5
37-6
41.7
Hi. 8
41.0
41.4
42.6
42.9
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
oo
County
Coal
field
or
town
Mine
Proximate
analysis , ?
!
Date
of
analy-
Name sis seam
Moisture
Volatile
8
a
1
Sulfur
Ultimate
analysis ,
*
£ o z o received
Ash
softening Free
Btu tenpera- swelling
dry ture.F0 index
Hardgrove
grindabiiity
index
J«Rffl_DAlOTA (continued)
M'Lean
n
n
Mercer
"
n
n
n
n
Morton
n
n
Haunt
Rail
Ward
n
n
n
Underwood
n
n
Hazen
n
n
Zap
n
n
Glen Ullln
n
tt
White
Earth
Mlnot
tt
n
n
Figenskak
n
n
Dakota
Star
n
n
Indian
Head
n
n
Rlchter
tt
n
Ttamel
Quality
Lignite
n
n
n
1947
1917
1947
1947
1917
1917
1917 Beulah
Zap
1917 "
1947 "
1947
1947
1917
1916
1916
1916
1946
1946
40.2
39-9
40.1
37.7
37.4
37.3
35.9
35.6
35-9
42.1
40.4
41.0
43.1
39.0
38.2
38.3
38.6
15.0
11.6
13-0
11.0
11.9
13-3
12.6
12.1
41.2
43.6
41.0
35.6
42.0
12.8
10.5
10.8
39.1
15.3
11.3
12.2
18.9
18.1
17.1
47.8
47.3
47.6
45.8
39.6
32.7
51.6
50.2
49.4
18.5
17.3
9-7
U.I
11.8
7-1
9.7
9-3
9.6
10.3
U.2
10.6
19.1
31.7
6.4
7.0
10.1
10.7
19.3
0.8
0.9
0.9
0.8
1.1
0.7
1.2
1.0
1.0
1.8
1.8
1-3
0.4
0-3
0.3
0.2
0.4
_
— —
4.5 66.3
_ _
4.3 65.9
_ _
-
1.4 64.1
_ _
-
1.1 66.9
1.4 66.2
_ _
_ _
-
_
— —
0.9 20.4
_ _
0.9 18.1
_ _
-
1.1 17.7
-
1.2 20.7
1.0 21.1
_ _
_
-
6,600
6,570
6,210
6,980
6,950
6,970
7,140
7,120
7,000
6,300
5,840
4,720
6,130
6,780
6,560
6,500
6,270
11,010
10,920
10,380
11,210
11,100
11,120
11,130
10,060
10,920
10,880
9,800
7,990
11,310
11,120
10,620
10,530
10,210
2,230
2,360
2,180
2,000
2,380
2,390
2,260
2,190
2,200
2,490
2,500
2,100
2,420
2,510
2,290
2,300
2,240
_
-
-
_
-
_
-
_
_
_
-
Coos Bay
OREGON8
16.3 34.6 11.1 8.0 0.6
11,950
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
oo
County
Coal
field
or
town
Mine
Proximate
analysis , <
§
Date
of
analy-
Narae sls seam
Eden Ridge Argo
Anderson
" Argo
Carter
Rogue
River Valley
Dewey
n
n
Carbon
n
n
n
n
rt
n
n
Tf
Ftresteel Mresteel
n n
n it
Helper
It
n
n
n
it
ti
it
n
n
ti
ti
Carbon Fuel
n
Liberty
n
Ji
it
n
Spring
Canyon No. 7
n
n
n
IT
Castle
Gate B
n
Castle
Gate B i
Liberty
ti
n
n
Castle
Gate D
n
11
H
1
"4.6
2.7
9.1
33.4
32.8
32.1
4.5
4.8
5.5
5.3
5.5
6.3
6.1
3.1
3.4
3.3
3.7
4.6
a
1
"IsTf
31-3
30.0
43.2
42.1
38.8
45-3
15.0
17.7
17.1
16.5
15.2
47.2
17-5
47.2
47.2
17-3
16.1
a
O
I
£
01
CREQCH
""31.7 32.6
28.2 10.5
31.8 29-1
SOOTH
46.7
42.8
38.5
I
17.4
47.4
47.7
48.3
46.6
47.2
46.3
41.6
45.0
45.1
11.9
15.8
10.1
11.8
22.7
__._.} i.
TSH1*'
7-3
7-6
1.6
4.3
6.9
7.6
6.5
7-9
7.8
7.7
7.8
3.1
Ultimate
analysis, If
m & S 55 o received dry
'• (continued)
1.5
'DAKOTA1'7
.9
1.6
1.4
.3 - -
-3
.9 - -
.9
1.0
-9 - -
1.0
.4
.4
.4 - -
.4
.4 - -
.
-
7,330
7,140
6,440
12,720
12,640
13,070
13,090
12,730
12,150
12,630
12,990
12,950
12,890
12,820
12,680
8,350
6,900
8,500
11,000
10,630
9,490
13,320
13,280
13,830
13,830
13,480
13,290
13,440
13,410
13,410
13,320
13,310
13,290
Ash
softening Free
tetipera— swelling
ture,F° Index
-
2,210
2,020
2,080
2,160
2,270
1,990
2,080
2,080
2,080 2
2,080 2
2,130
2,090
2,130
2,130
2,130 1
Hardgrove
grindability
Index
-
40
.
-
48
40
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
-Cr
oo
03
Coal
field
or
County town
Carbon Helper
" Hiawatha
" "
n
it
"
"
'
"
M
it
Kenilworth
Rains
tl
Wellington
n
i it
i*
"
"
'Emery Castle
Gate
tt It
11 n
Carbon "
Mine
Proximate
analysis , *
g
a
Date fa
of 3
analy- -3
Mane sis seam £
firing
Canyon No. 7
King
tl
It
n
n
"
"
n
M
11
n
Kenilworth
Western
II
Knight
Ideal No. 2
If
Tl
n
11
n
n
Book Cliffs
n
ti
Clear Creek
Castle Gate
prep, plant
Castle 5-5
Gate D
7.2
6.0
7.1
7.3
6.2
7.0
6.1
6.1
7.0
6.7
5-6
4.0
3.9
4.5
3-5
4.4
5.5
3-7
5.4
1.9
6.2
Lower 5-7
Sunnyslde
5.7
6.2
Castle 8.2
Gate A
1 Volatile
17-3
13-5
115.1
44.5
15-9
45-5
46.2
45-9
45-3
15-9
1(6.1
16.9
45.3
47-3
47.0
41.4
40.8
40.7
41.3
1)1.1
41.3
40.7
41.2
41.0
41.7
43.7
a
v
•H
fc
1
Ultimate
analysis , t
£ 1 1
! I i
UTAH (continued)
45.4 7.3 .4 5.7 74.0
50.0
49.6
50.7
49.1
49.1
49.2
48.6
49.2
49-3
48.7
49.6
46.9
47.2
46.9
54.2
54.3
53-9
53-2
53.6
53-2
53.7
51.8
51.8
52.9
51-3
5.6
5.3
.8
5.0
5.4
4.6
5-5
5.5
4.8
5-2
3-5
7.8
5-5
6.1
4.4
4.9
5-4
5-5
5.3
5-5
5.6
7.0
7.2
5-4
5.0
.5
• 5 - -
.5 - -
• 5 - -
.5 - -
.5
.5
.5
.5
.4 - -
.5 - -
.3 - -
.6 - -
.7 - -
.!)
.4
.5 - -
.6 - -
.5 - -
.5 - -
.5 - -
.6
.6 - -
.6 - -
,1 - -
f & Btu
3 & as
s= o received
1.4 11.2 12,640
12,630
12,920
12,800
12,810
12,880
12,920
12,920
- 12,930
12,860
12,870
13,250
12,820
13,240
13,040
13,390
13,250
12,980
13,270
13,070
13,020
12,830
- 12,630
12,650
12,750
12,400
Ash
softening Free Hardgrove
Btu tempera- swelling grindability
dry ture.F0 index Index
13,380
13,610
13,760
13,770
13,810
13,740
13,890
13,770
13,770
13,830
13,800
14,040
13,370
13J80
13,640
13,880
13,860
13,740
13,790
13,830
13,710
13,680
13,400
13,420
13,600
13,510
2,090
2,080
2,050
2,060
2,050
2,060
2,050
2,040
2,040
2,050
2,080
2,050
2,180
2,080
_
2,180
2,220
2,190
2,150
2.130
2,410
2,490
2,620
1
_
_
-
_
2 V2
_
_
_
_
3
2 V2
_
_
_
_
_
_
_
-
_
_
-
_
-
48
_
_
_
_
-
_
_
—
_
_
_
_
_
-
_
_
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
oo
Coal
field
or
County town
Mine
Proximate
analysis, *>
1
Date
of
analy-
ffettns sis segjn
4-1
n
Volatile
i
o
1
£
I
Ultimate
analysis, *
3 s> 1 §
S, Stu
g as Btu
o received dry
Ash
softening
tenpera-
ture,F°
Free fanigrove
swelling grindability
Index index
UTAH (continued)
Carbon Castle
Gate
tt tt
tt ft
11 ft
it n
Helper
1 tt
Hiawatha
Rains
Scofleld
n tf
" Wellington
"
aery Wellington
tl 11
M It
Clear Creek
Castle Gate
prep, plant
it
Kenllworth
Kenilworth
4 Castle
Gate No. 4
Castle Gate
prep plant
n
Carton FUel
11
King
Western
Standard
Colomblne
n
Knight ,
Ideal lfo.2
n
Book Cliffs
it
"
Castle
Gate A
n
Castle
Gate B
n
n
Castle
Gate 6
tt
Lower
Sunnyslde
i*
"
n
9.6
8.2
4.3
3-1
5.6
5.2
6.5
3.*
3-0
4.4
6.7
3.6
1.3
7.3
8.5
3-8
5-9
4.9
6.0
6.4
5-9
11.2
42.8
13.7
12.3
12.8
13.1
13.0
15.0
U6.2
44.7
15.6
17-9
16.7
44.4
11.3
10.7
10.6
10.6
ito.8
11.1
10.7
51.1
51.7
18.6
50.1
49-3
50.1
51.0
48.0
17.1
48.5
48.2
46.8
46.4
49.5
48.1
53-3
53.4
43.1
52-5
52.6
52-3
4.7"
5.5
7.7
7.3
7-9
6.2
6.0
7.0
6.7
6.8
6.2
5.3
6.9
6.1
7-6
6.0
6.0
6.3
6.7
6.3
7-0
.5 5.4 76.0 1.4
.4 - -
.4
.5 - -
.5 - -
.4 - -
.4
.3
.4
.3 - -
.5 - -
.8
.8
.6 5.5 74.fi 1.4
.7
.6
.5 - -
.7
.6
.6
.7 - -
12.0 12,210
12,160
12,730
12,920
12,500
12,780
12,580
12,630
- 13,030
12,800
12,690
13,340
12,910
11.6 12,390
11,760
13,130
12,800
12,780
12,530
12,610
12,590
13,500
13,250
13,320
13,330
13,240
13,490
13,470
13,290
13,440
13,390
13,610
13,850
13,510
13,360
12,850
13,670
13,610
13,410
13,330
13,480
13,380
2,520
2,360
2.180
2,120
2,130
2.130
2,160
2,240
2,210
2,120
2,480
2,150
2,210
2,130
_
_
2,540
2,340
-
1
43
_ _
_
11/2 - .
_ _
-
-
1
-
_ _
_
-
21
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
vo
o
County
Bnery
Carbon
ti
tt
tt
11
tl
tl
11
It
It
tl
11
tt
tt
It
n
Etaeiy
ii
((
Coal
field
or
town
Wellington
Castle
Gate
tt
It
n
Hiawatha
IT
IT
Rains
it
n
IT
Wellington
tt
n
n
n
Dragerton
(Carbon
county)
»
n
n
Mine
Proximate
analysis , *
g
JT)
Date |
of 5
analy- -3
Name sis Seam sS
Book Cliffs
tl
Kenilworth
Carbon Fuel
»
it
King
II
tl
Western
tt
tt
tt
Knight
Ideal No. 2
ii
tt
n
Book Cliffs
H
Lower 5.8
Sunnyslde
6.6
4.1
Castle 4.5
Gate B
" 4.7
" 4.7
4.8
6.4
5.9
3.5
4.0
4.2
4.9
3.4
3-5
5.1
4.0
5.7
Lower 6.4
Sunnyslde
6.3
" 5-5
" 5.9
o
i-t
*H
1
41.1
41.0
43.8
45.8
45.7
45.6
47.0
45.9
46.1
46.9
46.0
44.6
45.0
40.7
40.9
40.7
40.8
40.5
40.4
40.8
40.6
40.5
a
o
•H
&.
52.3
52.5
48.0
47.3
47.4
47.3
46.9
48.4
47.7
46.9
47.2
46.9
46.8
54.1
54.0
54.1
54.4
54.1
51.5
51.0
51.9
52.0
1
UTAH
6.0
6.5
8.2
6.9
6.9
7.1
6.1
5-7
6.2
6.2
6.8
8.5
8.2
5.2
5.1
5-2
4.8
5.4
8.1
8.2
7-5
7.5
Ultimate
analysis, t
a £ 1
(continued)
.6 - -
.6
.4 - -
.3 - -
-3
.3
.5 - -
• 5 - -
'.1 - -
.7 - -
.8 - -
• 5 - -
.4 - -
.4
.4
.4 - -
1.0
.8 - -
.7 - -
.7 - -
^ H Btu
in x as
z o received
12,670
- 12,550
12,720
12,870
12,810
12,780
12,990
12,820
12,850
13,240
13,000
12,720
12,630
13,390
13,350
13,100
13,280
12,900
12,380
12,400
12,580
12,560
Ash
softening
Btu tempera-
dry ture.F0
13,470
13,440
13,300
13,480
13,450
13,410
13,650
13,700
13,660
13,720
13,550
13,280
13,280
13,860
13,840
13,800
13,830
13,690
13,230
13,230
13,230
13,340
2,490
2,520
-
2,250
2,270
2,060
2,140
2,190
2,200
2,180
2,220
2,200
-
2,350
2,450
2,430
2,450
Free Hardgrove
swelling grindabillty
Index index
-
_
_ _
2 V2
3
1 1/2
-
3 48
_
3
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
Coal
field
or
County town
Carbon Helper
n it
Hiawatha
-f H
VO n
M Price
" Scofleld
n n
n n
" Wattls
n n
Iron Cedar City
Carbon Castle
Gate
n n
it w
n ft
" Helper
n ti
Mine
Date
of
analy-
Nane si3 Seam
Carbon Fuel
Spring Canyon
Tipple
King
n
n
II
Gordon Creek
No. 01
Colonfclne
n
n
Star Point
No. 01
n
Webster
Kenllviorth
Prep. Plant
n
n
Carbon Fuel
Spring Canyon
Tipple
Castle
Gate B
Castle
Gate A &
Hiawatha
it
n
n
Castle
Gate A
Castle
Gate B
n
n
Hiawatha
n
Uricor-
related
Various
n
n
Castle
Gate B
Castle
Gate A &
Moisture
5-2
1.0
D
5-0
4.3
5.6
6.5
8.3
6.1
5.6
7.2
7-0
7.1
5-9
1.6
3.6
4.4
5.4
3.1
1.7
B
Proximate
analysis, 5
S
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
-Cr
vo
ro
County
Carbon
»
n
n
tt
it
ti
11
if
it
n
It
ft
11
it
n
Coal
field
or
town
Hiawatha
1
Castle
Gate
n
M
(I
ft
If
It
It
tt
Helper
"
ti
n
ti
tt
Mine
Proxiirate
analysis , t
1
Date
of
analy-
Nam» sis Seam
King
Kenllworth
Prep, plant
(Castle Gate No
Kenilwarth
Prep, plant
(Clear Creek)
Kenllworth
Prep, plant
{Kenilworth)
"
Kenllworth
Prep, plant
(Kenilworth &
Clear Creek)
"
"
n
Kenilworth
Prep, plant
Carbon Fuel
tr
Spring Canyon
Tipple
11
ii
"
Hiawatha
It
Castle
Gate C
.4)
Castle
Gate A
n
Castle
Gate D
n
Castle
Gate A &
D
tt
(1
If
Castle
Gate B
n
Castle
Gate A &
tr
if
11
Moisture
4.7
6.8
6.7
4.3
9-3
8.5
4.9
3-3
3.2
4.9
6.2
8.3
4.3
5.0
5-0
•3-7
B
3-6
3.8
3-6
0>
•H
46.0
46.5
46.2
44.1
45.8
46.3
44.6
44.8
tu.o
45.1
45.8
44.8
44.2
46.3
46.1
47-7
47.9
45-3
47.2
I
1
£
47.1
47.8
48.2
47.0
48.6
48.5
47.8
48.1
48.3
48.1
47-9
48.7
47.6
47-1
47.1
45.0
44.2
46.6
45.2
s:
w
UTAH
6.9
5.7
5-6
8.9
5.6
5.2
7.6
7.1
7.7
6.3
6.3
6.5
8.2
6.6
6.8
7.3
7-9
8.1
7-6
r-<
Ultimate
analysis, <
'o tj *3 >5 as
X 6 z o received
Ash
softening
Btu tenpera-
dry ture,F°
Free Hardgrove
swelling grindabillty
index Index
(continued)
• 5
.5
.'4
• 5
-5
.4
.4
.5
.5
-5
.5
• 3
-3
• 3
• 5
• 5
.4
.5
- - - - 12,890
- - - 12,770
- - - - 12,800
5.2 74-5 1.3 9.7 12,650
- 12,070
- - - 12,240
5.4 75.3 1.4 10.4 12,970
- 12,900
12,730
- - - 12,650
- 12,310
- - - 12,740
- 12,850
- - - 12,820
- - - 13,040
- - - - 12,870
- - - - 12,790
- - - 12,830
13,530
13,700
13,720
13,220
13,310
13,380
13,410
13,330
13,390
13,490
13,420
13,310
13,530
13,490
13,540
13,350
13,300
13,310
2,240
2,120
2,090
2,250
2,160
2.160
2,180
2,230
2,190
2,140
2,190
2,300
2,260
—
2,190
2,190
2, WO
2,190
3
2 V2 48
1 50
-
_
-
_ _
_
2
2 V2
_ _
- -
. _
-
_
-------
G-l UonUnued) . WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
4=-
VO
OJ
County
Carbon
ft
n
Bnery
Carbon
it
n
n
n
n
n
«
n
n
n
n
n
n
n
Query
n
it
Coal
field
or
town
Helper
n
Scofleld
Hiawatha
Hiawatha
n
n
n
n
n
n
Rains
Scofleld
ft
ft
tt
n
Wellington
n
Wellington
n
M
Mine
Proximate
analysis, *
1
Date
of
analy-
Name sis 5^^
Spring Canyon
Tipple
n
Colcnbine
Co-op
King
Western
Colombine
n
n
it
n
Soldier
Canyon
n
American
n
n
Castle
Gate A &
n
Castle
Gate B
Hiawatha
Castle
Gate B
n
n
tt
n
Rock
Canyon
n
Blind
Canyon
ti
n
£
•H
£
4.0
B
5.7'
ff' f
5-9
6.6
6.2
5-7
5.0
6.4
6.3
6.3
6.5
3.8
6.9
6.5
5.6
7-1
8.3
4.6
5.6
4.9
4.9
6.4
3
•H
s
£
47-3
46.8
44.6
46.4
45.8
45.9
46.0
45.6
46.0
45.8
45.6
46.6
45.1
45.5
45.8
45.5
44.7
42.0
40.4
45.6
46.5
48.7
a
o
1
*-i
&
44.8
45.0
46.9
46.1
48.3
49.0
47.4
49.2
48.0
48.2
49.7
43-9
48.3
48.2
48.4
48.0
46.6
49.4
51.6
46.5
45.4
43.6
1
UTAH
7-9
8.2
8.5
7.5
5.9
5.1
6.6
5.2
6.0
6.0
4.7
9.5
6.6
6.3
5.8
6.5
8.7
8.6
8.0
7-9
8.1
7.7
$
r-1
a
Ultimate
analysis, %
I g 1 | Btu
i§ •£ -P >> as Btu
£ 8 z 6 received dry
Ash
softening
tenpera—
ture.P0
Free Hardgrove
swelling grindabillty
index index
(continued)
.6
.6
.6
.4
.6
'.6
'.6
.6
.7
.4
.6
.5
.5
.5
.7
.5
.4
.4
.4
.4
- 12,800
_ 12,490
_ 12,160
_ 12,190
_ 12,820
12,930
- 12,920
_ - 12,840
_ 12,820
_ 12,800
_ 12,930
_ _ - - 12,560
5.3 73-7 1.3 12.5 12,250
_ 12,440
- 12,710
_ 12,340
- - - - 11,550
_ 12,450
5.1 74.6 1.5 10.4 12,360
12,910
_ 12,880
5.8 75.0 1.4 9.7 12.C20
13,330
13,240
12,920
13,480
13,670
13,710
13,600
13,710
13,680
13,660
13,840
13,060
13,160
13,300
13,460
13,280
12,590
13,050
13,090
13,570
13,540
13,700
2,190
2,260
~
2,110
2,100
2,410
2,150
2,380
2,210
2,220
2,320
2,170
2,280
2,370
2,350
2,240
2,430
2,440
2,050
2,250
2,190
-
1 1/2
"
-
3
3
1 1/2
1 1/2
1 1/2
-
2 1/2
-
-
—
-
-
43
47
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
Coal
field
or
County town
Mine
Proximate
analysis ,
n
Date
of
analy-
Naroe sis Seam
to
•H
Volatile
&
c
%
1
Ultimate
analysis , %
1 1 I
c
g & Btu
£ 5? as
2 o received
Ash
softening
Btu tempera-
dry ture,F°
Free Hardgrove
swelling grindability
index index
OTAH (continued)
Carbon Castle
Gate
H ii
" Helper
ii ti
"
"
" "
Hiawatha
Kenilworth
Rains
11
tt tt
" Wellington
ii tt
n n
ti ti
ir it
Query Columbia
ti H
M n
tt M
tt n
Castle
Gate
Prep, plant
n
Carbon
Fuel
King
Kenilworth
Western
n
tt
Knight-Ideal
No. 2
H
"
it
M
II
Book Cliffs
II
II
tt
ft
Castle
Gate C,D
& B
11
Castle
Gate B
"
u
11
Castle
Gate D
Gilson
n
ti
n
it
"
Lower
Sunnyside
ti
n
"
ti
4.3
5.2
3.7
3.8
3.7
1.1
4.3
5-7
5.4
1.4
1.4
3.0
3.2
2.9
1.5
5.1
4.9
5.0
5.5
6.7
6.7
6.3
3-8
5-9
5.8
43.7
11.3
11.3
44.1
11.5
15.0
15.2
16.1
15.1
15.1
43.1
48.7
16.6
16.1
11.3
10.5
10.9
10.8
11.1
11.2
10.0
10.1
10.1
40.2
10.1
48.2
19.4
50.5
50.8
48.1
18.0
48.2
48.2
47.2
17-7
18.7
15-3
19.0
16.9
51.1
51.3
53.7
53-8
52.9
53.5
52.8
52.1
53.0
53.0
52.8
8.1
6.3
5.2
1.8
7.1
7.0
6.6
5.7
7-4
6.9
7-9
6.0
4.4
7.0
4.3
5.2
5.4
5-4
6.0
5-3
7.2
7.2
6.9
6.8
6.8
.5 -
• 5 - -
.1 - -
.1 - -
.3
.3 - -
.1 - -
.1 - -
.6 - -
.6 - -
.4 - -
1.1
.6 - -
1.0
.1
.1 - -
.1 - -
.1 - -
.1 - -
.1
.7 - -
.7 - -
.7 - -
.7 - -
.6 - -
12,710
12,780
13,190
- 13,320
12,900
12,800
- 12,950
12,820
- 12,730
13,030
12,690
13,100
13,160
13,100
13,290
13,010
13,070
13,040
12,880
12,810
12,500
12,580
12,950
12,680
12,690
13,310
13,490
13,690
13,840
13,390
13,100
13,520
13,590
13,170
13,630
13,290
13,820
13,900
13,500
13,910
13,710
13,710
13,720
13,610
13,730
13,110
13,440
13,470
13,480
13,190
2,180
2,210
2,210
2,230
2,210
2,300
2,210
2,230
2,230
2,270
2,240
2,180
2,150
2,170
2,150
2,180
2,180
2,190
2,180
2,480
2,370
2,430
2,190
2,420
17
11/2
_
_ „
_
1 1/2
-
_
_ _
_ _
_ _
_ _
_ _
_ _
_ _
2
_
_ _
_
_ _
-
-------
Table G-l (continued'). WSTERN COAL COMPOSITION & PHYSICAL PROPERTIES
vo
Ul
County
Carbon
tt
n
ft
n
n
«
n
it
Bnery
n
n
Carbon
n
n
n
n
n
tt
tt
IT
tt
Coal
field
or
town
Helper
Hiawatha
n
n
Price
n
Wattls
n
n
Bnery
Huntlngton
n
Helper
Hiawatha
Wattis
n
n
Clear
Creek
Helper
tt
tt
ft
Mine
Proximate
analysis , ?
I
Date | 3
of 3 4£
analy- | 3
Name sis Seam £ >
Carbon Fuel
King
n
n
Gordon
Creek No. 2
n
Star Point
No. 01
n
n
Browning
Deer Creek
"
Carbon
Fuel
King
Star Point
No. 01
n
n
O'connor
No. 2
Carbon
Fuel
n
tt
n
Castle
Gate B
Hiawatha
n
n
Castle
Gate A
Various
Hiawatha
n
Ferron J
Blind
Canyon
tt
Castle
Gate B
Hiawatha
n
if
n
Castle
Gate B
tt
tt
tt
6.2 13.1
6.0 15-9
6.1 15.7
5.8 15.1
5.3 16.7
6.0 16.5
6.0 13.0
5.5 13-1
6.9 11.9
1.3 10.7
8.0 15.1
5.6 11.6
5-7 13-5
6.1 15.1
1.1 12.6
5.5 11.7
6.6 12.0
8.7 11.2
2.9 16.0
2.8 15.3
1.1 15.5
1.1 15.1
§
1
a
15.9
18.2
18.1
19.0
15.3
15.1
11.6
16.6
11.5
52.3
17.5
17.1
16.8
18.3
15.8
15-5
16.6
19-9
16.2
17.6
17.5
17.7
1
UTAH
10.7
5-9
6.2
5-9
8.0
8.1
12.1
10.0
13.6
7-0
7.1
8.3
9-7
6.6
11.6
12.8
12.0
5.9
7.8
7.1
7.0
7.2
rH
8
Ultimate
analysis , %
p o p g, Btu
^ a S & as
§? 8 z O received
Ash
softening
Btu tenpera-
dry ture,F°
Free Hardgrove
swelling grindability
Index Index
(continued)
.5
.7
.7
.6
.5
.6
.7
.6
.7
.1
• 5
• 5
.5
.8
.5
.6
.7
.5
.3
.3
.3
.3
- - - 12,120
- - - 12,850
- - - 12,730
- - - 12,790
5.1 73.1 1.6 U.I 12,580
- - 12,160
- - U.670
- - 12,210
U.370
5.2 75-5 1.1 10-5 12,710
5.6 75.1 1.1 10.3 12,150
- - 12,620
- 12,330
- - 12,700
- - 12,070
11,730
11,630
_ 12,200
13,000
_ - - 13,080
- - - 12,820
- - - 12,790
12,920
13,670
13,600
13,580
13,280
13,250
12,120
12,920
12,210
13,310
13,530
13,370
13,070
13,520
12,630
12,110
12,150
13,350
13,390
13,160
13,130
13,380
2,360
2,250
2,250
2,210
2,160
2,350
2,710
-
2,620
2,130
2,110
2,110
2,320
2,310
2,830
2,820
2,710
2,730
~*
2,280
2,270
2,230
5-V2(l) -
-
— -
- -
13
2
- -
— —
— —
1-V2 10
2-1/2 15
— ~
-
1-1/2
_
1 18
"
-
-
— —
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
ON
Proximate
analysis ,
County
Coal
field
or
town
Mine
Date
of
analy-
Mame sis
Seam
t n -ri
S 0 2
1
Btu
as
received
Btu
dry
Ash
softening Free Hardgrove
tenpera- swelling grindability
ture,F° Index Index
UTAH (continued)
Carbon
||
"
n
it
it
"
it
it
it
"
It
Qnery
it
tt
ti
it
Carbon
n
11
ti
it
Hiawatha
n
«
"
Kenilworth
it
Rains
«
ti
Wellington
"
"
Dragerton
ft
tt
it
"
Hiawatha
Lower
Sunnyside
«
if
KlJig
"
tf
"
Kenilworth
u
Western
n
n
Knight Ideal
No. 2
Soldier
Canyon
"
Book Cliffs
ii
it
tt
"
King
Columbia
n
Horse
Canyon
Surmyslde
Castle Gate
Sub Ho. 1
tt
tt
n
Castle
Gate D
11
Castle
Gate No. 1
n
n
Gilson
Rock
Canyon
ti
Lower
Sunnyside
N
M
M
"
6.0 45.7
4.7 46.1
6.0 46.0
6.3 45.1
4.1 43.9
4.5 43.6
3.8 16.9
3-3 47.0
4.2 46.9
5-3 10.7
5.6 10.7
4.3 40.7
5.0 10.5
6.0 40.9
6.0 40.9
5-3 40.9
6.0 41.2
5.0 43.2
4.6 38.8
5.4 38.1
5.0 38.5
3.4 38.5
48.0
48.0
48.0
48.1
49.0
48.8
47.8
47.3
47.3
53.5
52.0
52.5
52.8
52.5
53.0
52.1
52.2
16.6
50.6
50.4
49.9
50.8
6.3 .6
5-9 -5
6.0 .6
6.8 .6
7.1 .4
7.8 .H
5.3 .8
5-7 .8
5-8 .7
5.8 .5
7-3 .4
6.8 .4
6.7 -7
6.6 .7
6.1 .6
6.7 .6
6.6 .6
5-2 0.5
6.0 1.0
6.1 1.0
6.6 .8
7-3 1-2
_
_
_
_ _
_
_ _ _
_
_
_ _ _
_
5.2 75.5 1.4
_
_ _
- — —
_ _
_
- -
6.0 72.4 1.5
5.7 72.9 1-5
5.6 72.2 1.5
5.6 72.4 1.5
5.6 73.2 1.6
_
-
_
-
-
-
-
-
-
-
10.2
-
_
—
_
_
-
14.4
12.9
13.6
13-1
11.1
13,090
13,090
12,920
12,740
12,820
12,710
13,290
13,310
13,140
12,860
12,610
12,730
12,830
12,710
12,740
12,780
12,660
13,750
13,970
13,860
13,920
—
13,730
13,730
13,750
13,610
13,380
13,310
13,830
13,800
13,720
13,580
13,360
13,310
13,520
13,530
13,560
13,510
13,490
-
-
-
-
~
2,100
2,100
2,090
2,250
2,180
2,160
_
2,120
2,140
2,160
2,460
2,330
_
2,390
2,450
2,430 3(D
2,480 2 V2(l) -
_
_
-
- - -
_ — —
-------
Table G-l (.continued). VJESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
vo
County
Carbon
n
n
n
n
n
finery
n
Ircn
San Pete
Coal
field
or
town
Lower
Sunnyside
n
n
n
n
n
Blind
Canyon
n
Sunny-
side
Unknown
Mount
Pleasant
Mine
Date
of
analy-
Narre sis Seam
Sunnyside
n
n
it
Unknown
n
Unknown
Horse Canyon
Coredlrt
Unknown
Unknown
Proximate
analysis, "
I
•P
i
1.5
3-7
3-5
5.9
1.9
5.8
5.5
4.7
3.1
11.3
3.0
rH
.rl
.p
a
rH
38.5
38.9
38.9
38.6
38.3
37.1
11.6
39-1
39-0
31.7
15.2
3
O
V
£
51.2
50.5
52.3
49.8
19-7
19.6
44.8
50.1
52.8
15.7
15-5
1
UTAH
5.8
6.9
5.3
5-7
7-1
7-5
5.1
6.1
5.1
5.3
6.3
Ultimate
analysis, <
S
h p
1 I'
(continued]
1-3 5.6
1-5 5.5
1.1 5.6
1.0 5-7
.8 5.6
1.2 -
.1 6.2
.8 5.6
.8 5.6
5.0 5-1
.6 5.8
§
i
73.6
73.3
71.5
72.1
71.1
-
73-1
72.6
75.1
57.0
72.9
<=
r
i
1.6
1.6
1.6
1.5
1.5
-
1.1
1.6
1.4
1.0
1.6
S
S
12.1
11.2
11.9
14.0
13.6
—
13.8
13-3
11.7
26.3
12.8
Coal Field
n
n
n
u
n
Carbon
n
n
Castle
Gate
District
„
n
n
H
n
n
Carbon Castle
Kiel Gate B
Castle Castle
Gate Gate D
Kenilworth "
3-7
3.1
3-7
3.2
1.7
1.5
5.1
1.1
12.3
13.0
13.0
12.9
12.2
15.8
13.5
13-9
18.9
15.5
15.8
15-3
13-9
17.3
50.2
49.0
5.1
8.4
7-5
8.6
9.2
6.9
6.3
7.1
.8 5-8
.8 5.8
.7 -
.6 5.7
.5 5.8
0.3 5-5
.2 5.8
.1 5-3
73.8
71.5
-
71.6
69.6
71-7
73-9
76.1
1.6
1.5
-
1.4
1.1
1.1
1.3
1.3
12.9
12.0
-
12.1
13-5
11.9
13.4
12.0
Btu
as Btu
received dry
14,020
14,280
14,360
13,880
13,840
— —
14,090
13,820
14,280
10,620
14,140
11,090
14,160
14,090
14,250
13,850
12,870 13,180
12,850 13,510
12,820 13,380
Ash
softening Free Hardgrove
tenpera- swelling grindability
ture.F0 index index
-
- - -
— — —
- - -
— - —
— — ~"
-
- - -
-
-
_ — —
"" ~" ""
_ — ™
•• ~~ ™
_ —
2,250 - 51
2,210 - 15
2,180 - 1J
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
\0
CO
Proximate
County
Carbon
it
it
n
n
n
ii
M
it
n
n
it
**
11
"
ti
Coal
field
or
town
Castle
Gate
District
ti
Gordon
Creek
District
n
n
Hiawatha
District
II
Pleasant
Valley
District
n
n
ti
n
ti
it
n
n
Mine
Date
of
analy-
Name s:i-s Seam
Panther
Royal
Blue Blaze
Gordon Creek
National
Sweet
Hiawatha
King No. 1
Wattis
Clear Creek
Columbine
Klnney
Winter
Quarters
Day
Liberty
Peerless
Rains
Spring
Canyon
Castle
Gate B
Castle
Gate D
Castle
Gate A
Hiawatha
Castle
Gate A
Hiawatha
Hiawatha
Wattis
Castle
Gate A
Castle
Gate B
Castle
Gate A
"
Spring
Canyon
"
"
"
Castle
Gate D
Moisture
3-9
3.2
6.1
12.6
6.6
5.8
6.1
7.1
9.6
6.8
8.1
6.9
3.9
4.9
4.6
4.8
4.1
0)
r— t
•H
i~)
41.6
43.2
44.9
43.6
45-3
45.5
45.9
44.3
44.2
45.0
41.4
43.1
44.9
45-5
44.2
44.9
45.7
§
O
1
49.1
49.5
48.0
51.8
47.9
48.0
48.6
48.4
51-1
49.3
44.9
44.8
47.4
46.6
49.4
46.5
47-3
1
UTAH
5-4
7-3
7-1
4.6
6.8
6.5
5-5
7.3
4.7
5-7
5.6
5.2
7.7
7.9
6.4
8.0
6.0
Sulfur
Ultimate
Hydrogen
!
Nitrogen
o
Ash
Btu softening Free
as Btu tempera- swelling
received dry ture,F° index
Hardgrove
grindabilitv
index
(continued)
.5
.4
.6
'.6
.6
0.5
.9
-5
.6
.9
.7
1.7
.8
.7
.6
.4
5.7
5.6
-
-
5.4
6.1
5-9
5-4
5-5
5.8
6.0
5.9
6.1
5.5
5.8
5-7
71.9
75.4
-
—
73.4
70.0
70.1
76.0
74.8
67.7
69.1
74.7
72.1
75.7
72.2
74-9
1.4
1.4
-
-
1.6
1.3
1.4
1.4
1.4
1.4
1.4
1-5
1.4
1.7
1.3
1.4
15.1
10.0
-
-
13.9
15.0
17-3
12.0
11.6
18.6
17.6
9.8
13-9
10.8
14.9
10.9
13,020
13,000
12,330
10,550
12,200
12,590
12,920
12,200
12,210
12,570
12,220
12,470
13,040
12,610
12,930
12,590
12,920
13,540
13,430
13,130
12,070
13,060
13,360
13,770
13,130
13,500
13,500
13,300
13,400
13,560
13,260
13,560
13,230
13,480
2,110
2,220
-
2,470
2,420
2,048
2,620
2,520
2,310
2,240
2,130
2,010
2,140
2,490
2,210
2,260
-
46
-
-
48
52
47
46
_
_
46
46
46
48
-------
Table G-l (continuedV VIESTER8 COAL COMPOSITION & PIftSICkL PROPERTIES
Coal
field
or
County town
Mine
Proximate
analysis, <
8
•p
Date
of
analy-
Name sis Seam
| |
Q O
s >
S
1 *
e s
Sulfur
Ultimate
analysis, I
I I
z 8
Btu
as Stu
received dry
Ash
softening Free
terpera- swell IIP
ture,F° Index
Hardgrove
cTindatr.ltv
Index
OTAH (continued)
Carton Pleasant
Valley
District
it n
n ft
_ Carbon Sunnyslde
VQ District
Co " "
Carton Upper
Huntlngton
Canyon
n it
Carbon Wellington
District
it n
n n
n n
it tt
n n
Baery Bnery
District
it n
" Hiawatha
Standard
Vulcan
Western
Columbia
Sunnyslde
'Larsen &
Rlgby
New York
Coal Creek
Knight Ideal
No. 1
Knight Ideal
No. 2
Jtock Canyon
Soldier
Canyon
Star Point
Browning
Sun Valley
Hiawatha
Mohrlard
Spring
Canyon
n
n
Sunny-
side
n
Castle
Gate A
n
Qilson
n
it
tt
Rock
Canyon
Castle
Gate A
Perron I
Perron A
Hiawatha
2.3 45.8
5.1 46.3
4.5 47.0
5.4 38.1
5.8 38.4
6.8 47.0
6.9 40.1
5.7 40.1
3.9 40.4
5.1 40.7
5.7 40.7
4.3 40.7
6.4 42.3
6.1 42.4
7.5 41.3
5.2 44.1
47.4 6.8
46.3 7.4
46.9 6.1
50.4 6.1
50.2 5-6
47-5 5-5
47.8 5.2
51.2 8.7
50.7 8.9
54.1 5-2
51.3 8.0
52.5 6.8
52.9 4.8
49.6 8.0
47.8 10.9
48.8 7.1
.6
1.6
.7
1.0
1.0
.7
1.1
-5
.4
.4
2.2
.4
.6
.6
.9
.7
7-0 72.9
5.9 74.2
5.7 74.6
5.6 72.2
5-8 72.7
5.8 67.5
5.7 69.9
_ _
5.2 75.4
5.2 74.4
4.9 73.0
- -
5.3 76.6
5.1 74.2
5.1 73-0
6.2 69.7
1.0 13.8
1.6 9.9
1.6 9.7
1.5 13.6
1.5 13.4
1.3 20.3
1.3 16.8
_ _
1.4 11.5
1.4 10.4
1.5 12.3
- -
1.5 11.9
1.3 11.9
1.4 10.9
1-5 15.5
13,480
12,690
13,040
12,920
13,080
12,490
12,440
12,240
12,460
13,100
12,610
12,730
12,680
12,520
11,650
12,658
13,200
13,370
13,670
13,660
13,890
13,410
13,370
12,980
12,970
13,800
13,370
13,310
13,540
13,330
12,590
13,351
2,190
2,040
2,080
2,650
2,820
2,200
2,110
2,430
2,350
2,200
2,230
2,330
2,100
2,130
2,360
_
47
_
-
_
-
48
44
43
47
45
47
39
43
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
o
o
County
Query
n
ti
n
it
it
Brery
M
ti
Brery
n
Grand
Sevier
n
San Pete
Coal
field
or
town
Huntington
Canyon
District
H
IT
n
11
"
Qrange-
vllle
It
n
Sunny-
side
n
Thompson
Muddy
Creek
Sallna
Canyon
Wales
Sterling
Wtne
Proximate
analysis, t>
S
a
Date £ .H
of 3 3
analy- -H rH
Nane sis Seam £ >
American
Bear Canyon
Co-op
Deer Creek
Learoaster
Paramount
Deseret
Blincl
Canyon
Hiawatha
Bear
Canyon
Bllni
Canyon
Bear
Canyon
Bliiri
Canyon
Hiawatha &
3.9 44.3
5.2 46.7
5.4 44.1
4.7 14-9
6.8 45.6
5.3 42.8
5.7 45.0
%
O
£
48.9
48.1
49.7
46.9
50.0
50.7
48.7
1
UTAH
6.8
5-2
6.2
8.2
4.4
6.5
6.3
1
Ultimate
analysis ,
!
!
%
£ fe
(continued)
.n _ ~ '_ _
• 5
.5
.5
.5
1.0
.6
6.0
-
_
-
5.8
5.6
77-9
-
-
-
75.9
74.6
1.5 9-9
-
-
-
1.5 10.7
1.5 10.4
Btu
as
received
13,090
13,180
12,970
12,800
12,930
12,850
12,840
Ash
softening Free
Btu terrpera- swelling
dry ture ,F° index
13,630
13,910
13,710
13,430
13,860
13,560
13,620
2,160
2,130
2,070
2,170
2,080
2,390
2,190
Hardgrove
grindabillty
index
48
52
48
47
67
48
50
Bear Canyon
Ollphant
Nilberg
Book Cliffs
Horse Canyon
Sego
Southern
Utah Fuel
Sevier
Valley
All Mlnes(7)
Sterling
Hiawatha
it
Sunny-
side
n
Chester-
field
Upper
Ivie
Ivie
Wales
Sterling
5-3 40.9
6.4 41.1
5-3 40.9
4.7 39.1
8.0 35-7
9.3 43.6
6.3 45-0
2.4 32-1
8.1 12.6
52.4
51.1
52.4
50.1
45.9
49.5
45.9
46.0
43.2
6.7
7-8
6.7
6.1
10.4
6.9
9.1
19.2
6.1
.6
-5
.6
.8
.7
.4
.6
3.7
.9
-
5-f
„
5.6
5.6
_
5.3
4.2
-
-
72.6
_
72.6
65.4
_
71.4
64.1
-
-
1.5 11.8
_
1.6 13.3
1.4 16.5
_
1-3 12.3
1.2 7-8
-
12,520
12,280
12,780
12,880
11,550
11,670
12,030
11,201
11,767
13,120
13,120
13,510
13,520
12,550
12,850
12,840
11,479
12,800
2,200
2,320
2,430
2,370
2,800
2,110
2,210
-
-
-
46
48
-
-
50
48
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
ui
o
Coal
field
or
County town
Jlntah Vernal
IT II
larbon Consumers
n
tt
n
TI
n
n
tt
n
Hiawatha
n
tt
n
1 Kenllworth
i «
1 IT
Mire
Name
North St.
Warden
Sweet
n
tt
n
n
n
n
King
ti
Kenll-
worth
it
it
5
Date
of
analy-
sis Seam
ar
1917
1919
1950
1919
1950
1950
1917
1919
1917
1918
1919
1950
1918 King
1919 Hiawatha
1950 "
1950 "
1918 "
1919 "
1918 "
1919 "
1950 "
1918 Kenll-
worth
1919 "
1918 "
%
M
*
8.5
8.2
8.1
7.8
6.1
5.6
5.1
1.6
8.7
5.8
11.7
11.6
1.2
5.8
5-2
1.9
5.1
1.8
6.6
1.8
5-8
1.6
1.9
3.0
3.0
3.1
Pr
are
4)
tH
•H
In
1
31.3
37-3
15-7
15.2
15.2
15.0
15.1
15.2
11.7
11.1
11.6
11.8
15.5
13.5
11.3
11.3
11.1
13.8
11.1
11.7
15-5
11.6
11.2
11.2
11.3
•oxlmat
ilysis.
o
s
£
17.2
18.0
19.1
19-5
19.6
19.8
16.7
17.8
17.0
19-3
17.2
18.3
19-3
18.0
19.0
18.1
18.1
17.7
18.9
18.7
18.9
16.9
18.1
18.2
19.1
19.2
a
"t
in
UTAH
10.1
17-7
5.2
5.3
1.9
5-0
7.8
6.8
7-8
6.0
8.1
7.2
5.9
6.5
7.5
7.6
7.6
7-9
7.3
7-2
6.1
7.6
7.0
7.6
6.7
6.5
Ultimate
analysis
E, 1 g
•§ °£
3 £ a
(continued)
1.6 5-3 62.8
1.9
0.5 5.1 73-1
'.6
-5 - -
.5 - -
.7 - -
• 5 -
'.6 - -
.5
'.6
.8 - -
.7
.6 - -
.6 - -
.7
.7 - -
.6 - -
.6
.6 - -
• 5
.5
.5
*
c? K. Btu
4^ >> as
z o received
1.0 19-3 11,250
10,150
1.6 13.9 12,160
12,190
12,850
12,750
12,110
12,730
11,590
12,510
10,960
10,830
- 12,510
- 12,590
- 12,650
- 12,650
12,610
12,760
- 12,500
12,680
12,710
12,680
12,710
12,850
12,800
12,950
Btu
dry
12,290
11,380
13,230
13,510
13,680
13,510
13,150
13,310
12,700
13,280
12,110
12,250
13,100
13,360
13,310
13,000
13,320
13,100
13,380
13,320
13,190
13,290
13,370
13,250
13,200
13,360
Ash
softening Free
tenpera- swelling
ture,F° index
2,710
2,570
— —
2,630
2,360
2,120
2,120
2,120
2,110
2,150
2,360
2,390
2,100
2,190
2,280
-
-
Hardgpove
grindability
index
16
-
""
-
-
-
—
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
ui
o
no
County
Carbon
II
II
IT
n
it
n
M
n
t!
«
n
Coal
field
or
town
Latuda
11
National
n
n
it
M
If
Rains
Royal
n
Seofield
Mine
Name
Liberty
"
MoGowan
H
It
n
National
ii
n
Rains
No. 2
Royal
No. 2
it
Cox &
Smith
Proximate
analysis , "-
I
Date
of
analy-
sis
1948
1948
1950
1950
1950
1950
1950
1948
1949
1950
1950
1948
1950
1949
Sean
Liberty
Sub No. 3
tr
Castle
Gate
11
n
u
Gordon
Creek
11
11
M
Castle
Gate No. 2
ti
Castle
Gate
»
43
[Q
•H
i
3.8
4.9
5.3
5.9
4.5
6.1
6.1
6.6
6.6
8.1
2.9
2.8
2.4
13.6
t)
rH
•H
•8
1
46.6
45.5
46.2
46.9
46.3
44.9
46.2
45.4
45-3
45.4
44.9
45.2
43.6
44.0
%
O
1
•H
PH
47.4
46.6
48.5
46.6
46.5
48.0
47.8
47.6
47.9
47.9
47.3
45.1
48.4
49.6
.c
to
<
UTAH
6.0
7-9
5-3
6.5
7-3
7.1
6.0
7.0
6.8
6.7
7.8
9.7
8.0
6.5
Ultimate
analysis, %
e g
tj 60 C bC
3 >> 5 nH
ro £ d z
(continued)
.7 - -
.8 - -
.5
.4
.4
.6
.6 - -
.5 - -
.6
.6 - -
.5 - -
.7
.6
-5 - -
a Btu
5 as
o received
13,150
12,610
- 12,830
12,700
12,730
12,330
12,660
- 12,190
12,200
12,280
- 12,990
13,000
10,700
Btu
dry
13,670
13,260
13,540
13,500
13,330
13,130
13,480
13,050
13,060
13,360
13,320
13,320
12,390
Ash
softening free HanJgrove
tenpera- swelling grindabllity
ture,P° index index
-
2,170
-
-
2,660
2,470
-
-
2,270
Upper bench
it
»
ir
n
Spring
Canyon
"
n
Spring
Canyon
n
1949
1949
1949
n
Castle
Gate B
14.5
4.4
2.9
42.1
45.1
45.0
50.7
48.6
48.3
7.2
6.3
6.7
.5 - -
.5 - -
.4 - -
10,250
12,910
13,030
11,990
13,500
13,420
2,230
-
2,520
-------
Table G-l (continued). VIESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
Ul
o
LO
County
Carbon
n
n
, H
n
n
n
n
tt
it
tt
n
tt
n
n
n
tt
tt
n
n
ft
tt
t)
it
n
Coal
field
or
town
Spring
Canyon
n
n
n
n
Standard-
vine
tt
n
tt
n
n
tt
n
tt
Union
Wattis
Wellington
tt
Mine
Name
Spring
Canyon
n
n
n
n
ft
Standard
Gordon
Creek
Wattis
Coal
Creek
n
Date
of
analy-
sis Seam
1950
1950
1948
1949
1950
1948
1950
1948
1948
1949
1950
1948
1948
1950
1948
1948 No. 2 Sub
1948
1948
1948
1950
1950
1948
1950
1950 Aberdeen
1950 "
i
3.7
3-7
4.3
3.1
3.0
5-5
2.4
2.6
2.4
2.7
3.0
5.2
4.4
2.7
4.7
12.6
5.0
5-5
7.8
6.1
7-0
7.4
6.3
4.0
4.6
Pr
ana
> as
z o received
12,960
12,810
12,760
13,060
- 13,050
12,610
- 13,530
- 13,050
- 12,950
- 13,160
12,980
12,430
12,530
12,970
- 12,520
10,550
12,620
12,440
12,060
12,370
12,280
12,330
- 12,330
12,460
- 12,510
E
Btu
dry
13,460
13,300
13,330
13,480
13,450
13,340
13,860
13,390
13,270
13,530
13,380
13,120
13,110
13,330
13,140
12,070
13,280
13,160
13,080
13,170
13,200
13,320
13,160
12,980
13,110
Ash
oftening Free
tenpera- swelling
ture.P' index
-
2,220
2,180
2,200
-
-
2,230
2,200
2,160
2,190
-
2,620
2,500
2,470
2,910
-
2,470 0
Hardgrove
grlndability
index
-
-
-
-
-
—
-
-
0
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
Mine
County
Carbon
ti
H
n
n
U1
o
-Cr
King
11
11
11
ir
Klttitas
H
King
IT
fl
Coal
field
Of
town
Wellington
M
M
tl
II
Name
Coal
Creek
IT
tr
it
n
tt
Date
of
analy-
sis seam
19^9
1950
1950
1949
1950
1950
Aberdeen
it
n
it
n
tt
fc
ra
•H
£
3.6
4.6
3-3
4.7
4.9
4.2
Proximate
analysis , *
1
OJ
rH
•H
la
rH
£
40.6
41.1
40.5
40.7
41.0
40.9
1
o
lii
s ^
•H 03
fL< •£
UTAH
51-3 8.1
51.5 7.4
51.2 8.3
51.7 7-6
50.4 8.6
50.8 8.3
Ultimate
analysis ,
£
^ If J
1 * 1
(continued)
.5 - -
.5 - -
• 5 - -
.6
.5 - -
.5 - -
%
g
$ | Btu
£ % as
2 o received
12,550
12,600
12,560
12,470
12, ,320
12,430
Btu
dry
13,020
13,210
12,990
13,090
12,960
12,980
Ash .
softening Free
tempera- swelling
tur-e.F0 index
2,430
2,360
2,330
Hardgrove
grindability
index
-
WASHINGTON4 7^e
Black
Diamond
H
n
11
Ravendale
Roslyn
Franklin
No. 10
n
Rogers
No. 2
M
Black Knight
ftoslyn
No. 10
it
Roger
ti
Black
Knight
4.6
8.0
10.7
14.4
17-1
5.3
36.3
37.1
45.9
40.7
41.6
38.1
44.9 18.8
46.4 16.5
48.6 5-5
50.1 9-2
46.9 11-5
46.1 15.8
.6 - -
.6 4.9 67.6
•6 5.5 73-0
.7 - -
-5 4.9 66.4
.4 -
Prep, plant
ii
ii
Black
Diamond
"
ir
n
11
Palmar
Nos. 10
12
M
*'
1949
&
1950
1949
Franklin
Nos. 10 &
12
H
n
4.8
5.2
5.8
6.7
7-1
38.0
38.0
42.2
40.7
40.8
46.4 15.6
46.0 16.0
44.2 13.6
44.0 15-3
47.2 12.0
.3 - -
.4
0.6
.6 - -
.6
11,180
1.4 9.0 11,120
1.9 13.5 11,660
10,620
2.1 14.6 9,670
11,620
11,720
11,630
11,740
11,370
11,820
11,720
12,090
13,050
12,410
11,660
12,270
12,330
12,270
12,460
12,190
12,720
2,890
2,890
2,180
2,620
2,390
_
-
2,910
2,890
2,910
-
1
-
-
_
-
-------
Table &-1
COkL COMPOSITION t
PROPERTIES
VJ1
o
v_n
Mine
County
Coal
field
or
town
Name
Date
of
analy-
sis Seam
King Cuntoerland Olson 19^8
No. 1
" » Pavendale 19*19 Nos. 3,
No. H 3 V2, H
Kittitas Cle Elum Ranald 19^8 Big
No. 2
n n n 1948 "
« « Russell- 19^8 Roslyn
Gillett
« n » 1948 H
» Ronald Ranald 19^9 No. 6
n
n
it
tt
it
tt
tt
tt
tt
tt
it
n
Roslyn
tt
it
tt
tt
«•
it
tt
it
tt
it
n
No. 4
Raslyn
No. 3
n
n
H
Roslyn
No. 9
»
• fioslyn
Nos. 3
tt
tt
tl
tt
It
tl
1950 Roslyn
1948 "
1950 "
1950 "
1950 "
1948 "
1949 "
& 9
1950
1948
1950
1949
1948
1949
tn
•H
£
3-7
9-9
3.2
4.5
8.1
10.1
2.6
2.9
6.9
2.7
4.9
3.4
7.2
4.2
3.5
2.9
3-0
2.6
3.3
7-3
Proximate
analys? 3 , *
I
•H
43.2
40.1
36.9
38.4
40.3
40.1
37.0
40.5
39-9
39.3
38.9
40.5
39.9
40.0
39.7
40.5
39-9
40.9
41.3
39-4
a
V
1
•H
1
1
Ultimate
analysis,
5? o
WASHM3TON (continued)
43.7 13.1 .8 - -
44.2 15-7 .8 - -
44.8 18.3 -4
46.4 15.2 .3 - -
47.1 12.6 .4
47.3 12.6 .4 - -
47.1 15.9 .5 - -
48.9
47-5
48.9
48.5
48.3
46.8
46.9
46.9
47.7
47.7
48.1
46.0
47.5
10.6
12.6
11.8
12.6
11.2
13-3
13.1
13.4
11.8
12.4
11.0
12.7
13.1
.4
.3
!4
.3
0.4
1.2
.3
.4
.U
.il
.5
-
5.5 72.5
5.4 72.9
5.4 72.7
5-3 41.1
-
*
c? g, Btu
S H M
z 6 received
12,160
10,450
11,550
11,950
- 11,150
12,180
13,140
1.9 7.2 12,150
1.9 7.6 12,880
12,410
1.8 8.5 12,730
1.8 8.2 11,850
- 12,310
12,310
12,750
12,520
12,920
12,540
11,870
softening Free
Btu tempera- swelling
dry ture,F° Index
12,620
11,600
11,930
12,520
12,410
12,500
13,520
13,060
13,240
13,050
13,190
12,770
12,850
12,760
13,130
12,910
13,260
12,970
12,800
2,880
2,850
2,910
2,360
2,280
2,360
2,360
2,360
2,330
2,350
Hardgrove
grindability
index
-
—
-
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
County
Coal
field
or
town
mne
Naiffi
Proximate
analysis , •"!
Date
of
analy-
sis Seam
Moisture
Volatile
y
O
1
E
1
Sulfur
Ultimate
analysis, %
It
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
v_n
o
County
Canpbell
n
n
Carbon
Crook
Frsfoont
ii
it
n
n
n
n
it
Hot
Springs
»
"
"
M
M
Coal
field
or
town
Gillette
n
it
Hanna
Aladdin
Hudson
Crosby
M
II
II
tt
tl
Mine
Date
of
analy-
Ifame sis
Uyodak
n
n
Hanna
No. 2
Stillwell
Hudson
n
it
Indian
Popsia
n
n
n
Big Horn
"
Gebo or
Owl Creek
M
M
II
g
n
01
•H
Seam S
Roland 26
" 25
26
Hanna 11
No. 2
15
16.
18.
22.
16.
18.
16.
22.
20.
Gebo 17.
17.
" 14.
13.
17.
16.
9
0
4
9
1
7
9
3
2
2
0
0
1
8
4
7
0
3
7
a
rH
4J
I
43.5
42.7
39.0
45-5
40.5
42.4
40.9
38.1
40.7
41.0
41.0
43.0
40.1
38.8
39.2
44.2
43.2
39.0
39-2
Proxln
inalysl
o
V
8
fi
44.2
46.2
46.0
46.5
39-8
53-0
52.8
51.2
46.6
53.8
53-6
48.8
48.1
52.3
52.4
51.1
51.8
54.7
54.6
ate
s, t
I
W
12.3
11.1
14.1
8.0
19-7
4.6
6.3
10.7
12.7
5.2
4.5
8.2
11.8
8.9
8.4
4.7
5.0
6.3
6.2
Ultiroat
analysis
g
h p1 §
i £ S
KMINQ't7>'.8,101,10<.
1.3
.9 - -
1.4
.3 - -
7.9
.6
.7 - -
.9 - -
1.1
.5 - -
.5
.7 - -
.8
.8
.9
.6 - -
.6
.8
.8 - -
e
, *
g
p Jj, Btu
£ &> as
z o received
8,360
8,540
8,130
10,730
8,930
10,450
10,000
9,220
9,560
10,130
10,510
9,410
9,150
10,080
10,150
11,160
11,350
10,570
10,630
Btu
dry
11,440
11,380
11,050
12,180
10,520
12,550
12,330
11,860
11,410
12,380
12,510
12,070
11,450
12,260
12,290
13,080
13,050
12,780
12,720
Ash
softening Free Hardgrove
tenpera- swelling grindability
ture.F0 index index
- - -
- - -
_
- -
_ - -
- - -
— — —
- —
— — —
- - -
- -
— — ••
-
- - -
— — —
— — —
— — —
- -
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
o
oo
Coal
field
or
County town
Mine
Date
of
analy-
Name sis
Proximate
analysis, t
1
Seam
Moisture
Volatile
&
o
1
e
1
WHMDO
Lincoln Dlanorxi-
ville
Lincoln Kemnsrer
n n
" Sublet
Sheridan Dletz
n
n
n
n
n
11
11
n
n
n 11
n ii
Ettamond-
ville No. 1
Adavllle
Keystone
No. 1
Kenmsrer
No. 5
Hotchkiss
No. 2
Acne
n
Carney
n
n
11
"
Kem-
nerer
5.
4
19.0
flda-
vllle
Willow
Creek
Monarch
18.5
2.7
21
3
19.6
IT
IT
II
11
11
T1
II
Tl
M
II
Carney
n
M
n
n
17
18
15
.3
.5
.7
51.9
16
21
21
19
22
23
22
21
22
22
22
.6
.5
.5
.8
.6
.2
.1
.8
.2
.0
.5
42.4
45.2
45.2
38.2
41.2
42.6
41.6
40.0
41.0
42.0
42.3
41.5
42.1
41.7
42.9
42*.9
44.7
44.6
45.4
43.8
52.0
50.9
50.7
56-3
52.8
52.3
53.0
55.1
53.5
52.3
52.2
50.4
50.8
49.4
49.4
46.7
42.2
50.5
50.3
19.8
52.1
5-6
3-9
1.1
5-5
6.0
5.1
5.1
4.0
5.5
5.7
5.5
5.5
7-5
7.5
7.7
5.1
4.9
4.8
5.1
4.8
4.1
Ultimate
analysis, %
3 p Q p
5 1 1 £
(continued)
.8 -
.6 - - -
.7
.9 - -
.6 - - -
.6
-7
.5 - - -
.7 - - -
.6 - - -
.7 - - -
.8 - - -
.7 - - -
.7 - - -
.9
.7 - - -
.6
.5
.5 - - -
.6
.5 - - -
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
Proximate
analysis , *
County
Sheridan
n
it
tt
11
ti
n
n
n
n
tt
n
rr
n
n
H
ti
tr
n
n
it
it
Coal
field
or
town
Dietz
n
n
n
n
n
n
n
n
n
tt
tt
n
n
n
n
tt
n
Mine
Date
of
analy-
Name sis
Carney
tt
n
ti
ti
11
ft
n
ft
Dietz No. 7
Kool
ti
n
Model
Monarch
n
n
n
Acme, Kool
Dietz, Model
Carney
Monarch
n
n
«H
Seam &
Carney 22.5
" 22.5
" 21.9
" 20.8
" 22.4
" 19.8
" 22.5
" 22.4
" 22.6
Dietz 23.5
No. 3
Monarch 22.5
" 18.6
V 24.2
Carney 22.7
Monarch 21.2
22.6
" 20.4
" 22.1
Carney 20.1
and
Monarch
" 19.8
" 20.6
" 20.9
41
H
•H
43.8
45.1
45.7
17-2
12.7
15.7
15.0
18.4
13.8
44.4
52.5
11.1
45.0
44.1
43.6
46.1
44.0
44.2
41.6
42.2
41.6
41.1
§
i
£
52.1
50.3
49.4
47.7
52.6
50.1
49.8
46.3
45.1
44.3
41.9
50.5
43.7
50.9
50.8
48.1
50.1
48.2
53.5
52.9
53.9
53.8
1
Wyoming
4.1
4.6
4.9
5.1
4.7
4.2
5.2
5-3
11.1
11.3
5.6
5.4
11.3
5.0
5.6
5.8
5.0
7.6
4.9
4.9
4.5
5.1
1
1
Ultimate
analysis, %
53
i? 3 i
g> Btu
& as
o received
Ash
softening Free
Btu tenpera- swelling
dry ture,F° index
Hardgrove
grindability
Index
(continued)
.5
.5
.4
.6
.5
.6
.4
.6
.6
.8
.5
.7
.9
.4
.7
.8
.7
.8
.6
.7
.6
.6
_ _ _
_ _ _
' _ _ -
_ _ _
_ _ _
_ _ -
_ - -
_ _ _
_ _ -
_
_
_ - -
-
— ~ ~
-
9,690
9,600
9,650
9,860
9,610
9,980
9,520
9,580
8,910
8,770
9,600
10,000
8,720
9,550
9,680
9,740
9,760
9,500
9,880
9,890
9,850
9,630
12,500
12,390
12,350
12,350
12,380
12,450
12,290
12,320
11,510
11,460
12,340
12,280
11,510
12,350
12,280
12,580
12,266
12,200
12,370
12,330
12,400
12,180
-
—
—
—
-
-
—
—
—
—
-
~
-
-
_
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
h-1
O
Mine
Coal Date
field of
or analy-
County town Kane sis
Proximate
analysis . *
I
Sean
g
•P
03
s
0!
i-H
•rt
•B
CO
I
&
o
V
2
1
Wyoming
Slieridan Acme, Kool
Diets, Model
Carney
Monarch
n it
n «
« n
it ti
» n
n 11
n n
11 it
n ti
it n
ft n
« it
II ll
it n
n n
M n
" Acme, Carney
Dietz and
Monarch
ft ff
ti it
M "
Carney
and
Monarch
«
n
n
IT
"
«
"
»
»
It
"
11
n
n
n
it
tt
ti
n
tr
20.5
20.4
22.8
20.6
20.5
18.4
21.7
21-3
21.7
19.6
20.0
18.5
21.8
20.1
20.6
21.7
20.1
15-5
20.8
19.1
17-4
11.3
12.0
40.1
11.8
12.5
43.2
11.2
42.2
41.8
42.4
42.2
42.7
11-5
42.7
42.1
42.0
42.6
40.1
40.8
42.6
40.9
53.1
53.1
52.3
53.7
53.0
52.2
51.4
53-5
53-7
53-1
53-3
51.6
52.5
51-9
53-1
51-1
51-3
53-5
55.3
53.1
5-3
4.6
7.6
1.5
1-5
1.6
4.4
1-3
4.5
4.5
1.5
5-7
6.0
5.4
4.8
6.9
5-6
6.4
3-9
4,0
5.1
Ultimate
analysis , %
c g
.3 p o p
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
Coal
field
or
County town
Mine
Date
of
analy-
Naroe sis
Proximate
analysis , %
I
Seam
Moisture
Volatile
3
O
£
1
Ultimate
analysis, f
1 I !
g £ Btu softening Free
£ >, as Btu tempera- swelling
2 o received dry ture,F° index
Hardgrove
grlndability
index
Vfyomlng (continued)
Sheridan
n
Sheridan Sheridan
n
tt
tt n
Sweet- Rock
water Springs
n n
n n
Acne, Carney
Dietz and
Monarch
Acme and
Monarch
n
n
n
n
Acne 4 1927-28
Monarch
" 1927-28
" 1928-29
" 1926-27
" 1927-28
" 1928-29
Black 1922-23
Diamond
Blair- 1913-H
town
11 1911-15
lion 1921-22
Carney
and
Monarch
Monarch
n
n
n
n
Monarch
M
tt
n
n
it
n
Rock
Springs
Ho. 1
Rock
21.6
20.2
19.2
17-5
21.0
20.5
17-8
20.0
19.8
19.7
20.7
21.7
19.6
7.9
7.1
11.0
10.5
11.1
12.8
10.0
12.1
39-3
11.2
11.2
12.0
11.9
10.9
11.1
11.3
13.6
12.1
11.1
53.1
53.9
52.1
51.8
53-5
55.1
53.7
53-6
53.0
52.1
53.1
53.1
18.6
52.5
52.0
53.3
6.1
1.7
1.8
5-2
1.1
5.3
5.1
5-2
5.0
5.7
5.7
5.8
7.1
3.9
5-9
5.3
.8 - - - - 9,710
.7 - -
.5 - -
.6 - -
.7
.6 - -
.7 - -
.7
.7 - -
.7 - -
.7 - -
.6 - -
.6 - -
.9
.9 - -
1.2
- - 10
10
- - 10
- - 9
9
10
9
9
9
9
9
9
12
- - 12
11
,010
,060
,210
,920
,910
,190
,910
,980
,970
,790
,680
,580
,170
,210
,180
12,380
12,510
12,150
12.370
12,560
12,500
12,100
12,130
12,150
12,120
12,310
12,360
11,920
13.510
13,220
12,900
-
—
—
—
—
—
"'
-
-
-
(Mines) Springs
" 1921-25 " 7.3 11.6 51.9 3-5 -9
12,580 13,570
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
ui
M
ro
Mine
County
Sweet-
water
n
n
it
n
ti
ti
11
Coal
field
or
town K&n£
Rock lion
Springs (Mines]
"
n
n
"
ti
" "
" Union
Date
of
analy-
sis
1921-22
1926-27
1923-24
1924-25
1925-26
1926-27
1924-25
1906-07
Pacific
n
n
ti
n
n
" Copen-
hagen
!i n
" Premier
M II
n n
II IT
n n
n n
n n
n ii
n n
Superior Super-
ior No
1928-29
1928-29
1925-26
1926-27
1927-28
1928-29
1928-28
1925-26
1926-27
1927-28
1928-29
1920-21
1
jP
J
3
Seam s
Rock 7.0
Springs
7-6
11.9
7.8
10.5
7.8
11.1
Rock 11.6
Springs
No. 7
Bock 10.2
Springs
No. 1
" 10.2
10.6
" 11.3
" 10.1
10.2
" 12.8
" 10.2
" 12.2
11.8
" 10.8
10.6
Proximate
analysis , ?
1
•H
-e
1
41.3
41.3
42.4
42.1
43.2
41.6
40.0
41.2
42.4
41.5
43.0
41.1
42.6
42.0
42.8
43.2
42.6
41.8
42.1
43.7
I
7
£
53-3
54.2
52.6
53-3
52.3
53-5
52.8
54.9
53-7
53.0
53-0
53.0
53-3
51.8
52.6
53.0
52.6
53-8
51.7
51.2
I
Wyoolng
5.4
4.5
5.0
4.6
4.5
4.9
7.2
3-9
3.9
5.5
4.0
5-9
4.1
6.2
4.6
3.8
4.8
5.1
6.2
5.1
Ultimate
analysis, %
g
§t< 60 C
1 c
$ I
Btu
o z o received
(continued)
.9
1.1
.9
.9
1.1
1.1
1.2
.9
1.0
1.1
.9
.9 - -
.9
1.0
1.3
.9 - -
1.1
1.2
1.2
1.0
11
12
11
12
- - 11
- - 12
11
,790
,440
,460
,260
,680
,330
.360
11,770
- - 12
- - 11
11
12
11
- - 11
- - 11
- - 11
- - 11
- - 11
- - 11
- - 11
,160
,950
,930
,050
,750
,620
,900
,550
,560
,620
,770
,770
Btu
dry
12,680
13,460
13,010
13,300
13,050
13,370
12,780
13,328
13,540
13,310
13,340
13,400
13,080
13,330
13,250
12,160
13,110
13,030
13,160
12,160
Ash
softening Free HanJgrove
ten|3era- swelling grindability
ture.P0 index index
_
_ _ —
_
_ _ _
— _ _
_
_
_ _ _
_ _
_ _
_ _
_
_ _
_ _
_ _
_ _
_ _ _
_ _ _
_ _ _
_
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
ui
M
U)
County
Sweet-
water
n
n
n
n
Weston
Albany
n
tt
n
tt
n
tt
tf
M
Coal
field
or
town
Superior
ti
n
n
Sweet-
water
Cantoria
Rock-
River
u
n
ir
Mine
Date
of
analy-
Narae sis
Super- 1922-23
lor No. 1
" 1919-20
" 1920-21
" 1921-22
Sweet- 1908-09
water
Antelope 1905
No. 1 &
3 & Jumbo
Rock River
n
ti
Rock Creek
n
n
J.P. White
Prospect
n
Proximate
analysis, %
I
1
Seam £
Rock U.I
Springs
No. 1
U.9
" U.6
9.5
Rock 8.6
Springs
No. 7
8.9
Un- 18.3
named
n _
ti _
20.5
H _
" 17.6
«
O
r-H
•H
"tO
1
41.6
42.7
42.1
41.5
42.1
40.1
30.1
36.8
45.0
29-3
36.8
44.2
33-8
41.1
45.6
a
o
•o
1
*H
49.8
49.7
50.3
50.3
52.0
37.1
36.7
45.0
55.0
37.0
46.6
55.8
40.3
48.8
54.4
1
Wyoming
8.6
7.6
7.6
8.2
5.0
22.8
14.9
18.2
13.2
16.6
8.3
10.1
1
Ultimate
analysis, %
c
I 1
C
| | Btu
C sj as
z o received
Btu
dry
Ash
softening Free Hardgrove
tempera- swelling grlndability
ture,F° index index
(continued)
1.3
1.2
1.3
1.3
1.2
4.4
.6
.7
.9
.6
.7
.8
1.4
1.7
1.8
-
-
-
-
4.5 59.7
5-5 73.0
5.8 48.2
4.5 60.7
5.3 72.7
6.0 54.2
4.9 65.7
5.4 73.1
11,300
- 11,340
- 11,310
11,510
12,180
10,000
8,460
1.1 15-8 10,350
1.4 19.2 12,660
.9 31-3 8,480
1.1 16.4 10,660
1.3 19.9 12,780
.9 29.2 9,590
1.1 16.5 11,630
1.2 18.5 12,630
12,710
12,870
12,700
12,720
13,330
10,980
-
-
-
-
- - -
. -
-
2,410
2,510
2,280
_ — —
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
on
M
-t=-
County
Big Horn
n
n
M
n
n
Campbell
H
it
n
"
n
n
"
n
n
H
n
n
n
it
tt
n
n
Coal
field
or
town
Manderson
n
n
H
tt
n
«
tt
it
tt
it
11
Gillette
tt
«
n
tt
11
it
n
n
tt
n
tt
Mine
Date
of
analy-
Naroe sis
Rogers
Gap in
n
Flagstaff
n
n
Hens ley
n
Peerless
it
H
n
tt
11
tt
it
tt
it
n
n
n
Tt
tt
It
Proximate
analysis , %
!
Seam
Un-
named
n
tt
n
n
n
Roland
ti
M
n
M
it
ti
n
n
tt
n
n
tt
»
ti
(t
n
to-
named
g
±>
10
i
14.9
_
_
16.5
-
-
27.0
-
31.9
31.1
31.0
32.6
36.9
33.3
-
-
33.1
36.9
31.6
32-9
-
30.8
o>
rH
•H
1
33.1
39.3
46.9
31.3
41.0
47.4
34.2
48.8
31.8
30.4
28.4
31.4
27.6
39.0
43.4
47-7
29.0
43-5
27.6
29.2
42.7
28.0
41.7
30.3
&
o
I
t
38.0
4H.6
53.1
38.0
45.6
52.6
29.1
39.9
30.6
31.9
32.0
29-6
30.9
31.8
47.7
52.3
32.6
49.0
30.9
33-3
48.7
31-3
51.2
33.9
!
Vfyondng
13-7
16.1
_
11.2
13.4
-
9.7
13.3
5.7
6.6
5.6
6.4
4.6
5.9
8.9
-
5.0
7.5
4.6
5.9
8.6
4.8
7.1
5.0
I
Ultimate
analysis , %
c
So c
5? 3
c
1
£
Btu
as
received
Ash
softening Free
Btu tenpera- swelling
dry ture.P0 index
Hardgrove
grlndability
index
(continued)
1.8
2.1
2.5
2.1
2.5
2.9
1.4
2.0
.4
.6
.4
.6
-3
.5
.8
.8
.5
.7
.3
.6
.9
.3
.5
.3
5-7 53-3
4.7 62.6
5.6 74.7
6.0 54.9
5-0 65-7
5.7 75.9
._ _
-
_
_
_
_
_
6.8 45.7
4.7 68.5
5.2 75.2
_
_ _
— „
_
_
_
- -
6.7 47.8
1.0
1.2
1.4
1.1
1.3
1.5
_
-
_
_
_
-
_
.6
1.0
1.1
_
_
_
_
_
_
-
.7
24.5
13-3
15.8
24.7
12.1
14.0
_
-
_
_
_
_
_
40.5
16.1
17-7
-
_
—
_
_
_
_
39.5
9,510
11,180
13,330
9,740
11,660
13,470
8,260
11,320
7,900
7,920
7,620
7,780
7,770
11,650
12,780
8,000
12,010
8,180
11,960
8,110
12,080
8,120
— _ _
_ _. _
- -
2,180
- -
- -
2,130
2,170
2,170
2,260
2,420
2,150
_ _
_ _
_ _
2,220
- _ _
- - -
_
_ _ _
2,190
2,180
_
_
_
_
_
-
„
_
_
_
^
_
_
_
-
_
_
_
_
_
_
_
_
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
ui
County
Canpbell
n
n
n
n
n
tl
n
Carbon
n
ti
n
H
n
it
it
tt
n
tt
tt
tt
tt
n
tt
it
Coal
field
or
town
Gillette
tt
Arlington
n
Baggs
n
it
n
n
n
H
n
n
n
it
it
Carbon
tt
n
Mine
Date
of
analy-
Nane sis
Peerless
n
Eve land
n
Canpbell
n
Country Bank
n
Cottontail
n
Coal Gulch
Prospect
Cut Off
Gulch Prospect
Muddy Bridge
tt
Mine
n
Muddy Bridge Ml
n
Carbon No. 2
n
Union Pacific
Prospect
It
Seam
Unnamed
n
Roland
n
Felix
n
Unnamed
n
ti
it
n
tt
ne
Carbon
n
it
n
n
3
32.0
32:8
31.0
21.2
26.0
24.0
20.7
25.0
8^3
-
11.9
-
13.2
«H
43.8
47.3
30.1
11.3
31-2
46.4
30.5
44.2
28.7
36.4
30.1
40.7
28.5
37-5
36.0
45.4
51.8
46.7
62.4
69.3
39.9
44.5
36.4
11.3
35.7
Proxira
inalysi
o
1
1
19.0
52.7
32.8
18.2
29.1
13.8
28.4
41.1
34.6
In Q
43.8
37-8
51.1
39-4
51.8
33.4
42.1
48.2
20.8
27.6
30.7
42.3
46.1
46.2
52.4
hi C.
43.6
ate
s, %
I
looming
7.2
5.1
7-5
6.6
9.8
10.1
14.7
15-7
in Q
19.0
6.1
8.2
8.1
10.7
9.9
12.5
7.5
10.0
9.5
10.4
5.5
6 —
• 3
7-5
Ultlmat
analysis
1 ! i
(continued)
.4 4.7 69.1
.4 5-1 74.5
.5 - -
.7
.6
•9 - -
1.4 - -
2.1
.9
1.0
1.4
1.0
1.3
1.1 5.4 51.8
1.4 4.0 65.4
1.6 4.5 44.7
.4 5.6 51.1
.5 3.7 68.2
.6 4.1 75-8
.9 -
1.7
1.9 ~ ~
, *
z o re
1.0 17.6 11
1.1 18.9 12
- - 8
11
7
11
7
10
-
8
11
8
10
.7 31.1 8
1.9 15.8 10
1.0 18.2 12
.7 34.7 8
1.0 16.6 11
l.l 18.4 12
™ ™
Ash
Btu softening Free
as Btu terrpera- swelling
celved dry ture,F° index
,750 - -
,660 - - -
,010 - 2,320
,770 - -
,710 - 2,320
,520 -
,210 - 2,090
,490 - - -
- - - -
,350 - - -
,290
,100 -
,650 - - -
,720 - - -
,990 - - -
,560 - - -
,420 -
,240 - - -
,490 - - -
"21-
_ _ _
_ _ _
_ _ _
Hardgrove
grindablllty
index
-
-
-
•"
-
_
_
'-
-
_
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
VJ1
M
0\
County
Carbon
n
"
n
it
ti
tt
it
n
ti
it
tt
tt
ti
tt
ti
ti
Coal
field
or
town
Carton
n
n
Copperton
"
n
ti
n
n
Dlxon
n
tt
ti
« .
II
tt
ft
II
Mine
Date
of
analy-
Naroe sis
Prospect
Carbon No. 7
n
"
it
Prospect
n
Abandoned
n
ti
it
Carbondale
tt
"
Sterap Spring
ti
"
Darling
n
"
Angler
n
n
it
tt
it
Proximate
analysis , %
1
Seam
Cartoon
n
it
"
tt
Unnamed
n
it
"
n
tt
tt
n
it
it
tt
n
n
tt
tt
it
n
it
tt
it
n
Q) fl)
ft iH
3 «H
ra at
•H rH
£ £
- 41.2
10.2 38.1
- 42.5
11.6 33-8
- 38.2
14.5 36.8
- 43.1
9.2 41.6
- 45.8
6.8 45.8
- 49.1
13.0 33.4
- 38.4
- 42.3
10.8 36.0
- 40.4
- 43.8
14.4 31.9
- 37-2
- 39.6
14.3 31.8
- 37-1
- 39-4
15.2 32.8
- 38.7
- 40.3
1
1
fi
50.2
42.5
47-3
44.3
50.2
44.5
51.9
44.8
49.4
41.1
44.1
45-5
52.3
57-7
46.3
51.8
56.2
48.6
56.8
60.4
48.9
47.1
60.6
48.5
57-2
59.7
to
Wyoming
8.6
9-2
10.2
10.3
11.6
4.2
5.0
4.4
4.8
6.3
6.8
8.1
9.3
-
6.9
7.8
5-1
6.0
-
5.0
5.8
-
3.5
4.1
-
1
Ultimate
analysis , %
c
60 C
p 5
*u Tj
c
I
1
Btu
as Btu
received dry
Ash
softening Free Hardgrove
tempera- swelling grindability
ture,F° index index
(continued)
1.6
1.2
1.3
1.2
1.4
.5
.6
.7
.7
.6
.7
1.1
1-3
1.4
2-3
2.5
2.7
.6
.6
.7
.5
.5
.6
.6
.7
.7
_ _
_ _
_ _
_ _
_ _
_ _
_ _
_ _
_
- _
_ _
5.7 60.4
4.9 69.4
5.4 76.6
5.8 62.8
5.1 70.4
5.7 76.3
5.8 62.4
4.9 72.8
5.3 77.4
5.6 60.7
4.7 70.8
5.0 75.2
5.8 59.9
4.8 70.7
5.0 73.7
_
_
_
_
_
_
_
_
_
_
-
1.4
1.6
1.7
1.4
1.6
1.7
.9
1.0
1.1
1.0
1.2
1.3
1.0
1.2
1.2
_
_
_
_
_
_
_
_
_
_
_
23.3
13-5
14.9
20.8
12.6
13.6
25.2
14.7
15.5
27.2
17.0
17.9
29.2
18.5
19.4
_
_ _
— _.
_ _
— _
_ _
_ _
_ _
_ _
_ _
_
10,720
12,320
13,590
11,220
12,570
13,640
10,800
12,600
13,400
10,600
12,730
13,130
10,530
12,420
12,950
- - _
_ _ _
_ _ _
_ — ..
— — _
— — _
_ ._ _
— _ _
— ~ _.
- _ _
— — -.
- -
_ _
— _ _
— - ~
_ _
_ _
- -
_ _ —
_ _
_ _
_ _
_ _
_ _
_
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
VJI
Mine
County
Carbon
n
n
n
n
n
n
"
n
tt
»
tt
n
tt
it
tt
n
n
tt
n
tt
n
tt
ti
Coal
field
or
town
Dixon
n
tt
n
n
ti
Fort Steele
II
It
Hanna
ti
n
n
n
tt
n
ti
Name
Martin
tt
"
linde
n
n
Petty
II
II
Hanna No.
n
n
n
ti
tt
tt
it
tt
Hanna No.
n
n
tt
tt
tt
Date
of
analy-
sis seam
Unnamed
n
tt
n
It
n
ti
ii
ti
1 Hanna
No. 1
n
n
n
n
n
n
tt
tt
2 Hanna
No. 2
n
"
tt
tt
"
Proxljnate
analysis, ?
g 3 1
3 •H
4^ .P T
•H r-l 5
15.8 33.3 17.5
- 39.5 56.1
- 11.2 58.8
16.1 29.0 38.6
- 31.6 16.0
- 12.9 57.1
7.5 37.8 18.8
- 10.9 52.7
- 13.6 56.1
9.6 12.7 10.1
- 17.2 11.7
- 51.1 18.6
11.8 11.7 10.2
- 17.2 15.7
- 50.9 19.1
10.1 11.0 11.9
- 15.6 16.6
- 19.5 50.5
11.5 12.6 39.3
- 18.1 11.1
- 52.0 18.0
12.0 36.9 11.9
- 42.0 50.9
- 15.2 51.8
I
Wyoming
3.1
1.1
-
16.3
19.1
_
5.9
6.1
-
7-3
8.1
_
6.3
7.1
7.0
7.8
6~6
7.5
6~2
7.1
i
3
Ultimate
analysis, %
g
60 C
p o
* i
c
c
S
E
1
Btu
as Btu
received dry
Ash
softening Free Hardgrove
tenpera- swelling grindablllty
ture.F0 index index
(continued)
.6
.7
.7
.6
.8
.9
.9
.9
1.0
.1
.1
.5
.1
.5
.5
.5
.5
.6
.1
.1
.5
.1
.1
.5
5.9 62.0
1-9 73.6
5.1 76.8
5-3 50.1
1.2 60.1
5.2 71.6
5.3 67.6
1.8 73.1
5.1 78.1
5.5 62.8
1.9 69.5
5.3 75.6
5.8 62.5
5.1 70.8
5.5 76.3
5.5 62.7
1.9 69.7
5.3 75.6
5.3 59.7
1.5 67.1
1.9 72.8
5.7 60.6
5.0 68.8
5.1 71.1
1.1
1.3
1.1
.9
1.1
1.3
1.8
1.9
2.0
1.3
1.5
1.6
1.0
l.l
1.2
1.3
1.1
1.5
.9
1.1
1.2
1.0
1.1
1.2
27.0
15.1
16.0
26.5
11.1
18.0
18.5
12.9
13.8
22.7
15.6
17.0
21.0
15.1
16.5
23.0
15.7
17.0
27.1
19.1
20.6
26.1
17.6
18.8
10,720
12,710
13,280
8,880
10,580
13,130
11,940
12,900
13,780
11,250
12,110
13,530
11,070
12,550
13,520
11,300
12,570
13,630
10,890
12,300
13,300
10,640
12,080
13,110
_ _ —
_ _ _
_ _ —
_ _ _
_ _ _
_ _ _
_ _ _
_ _
_ - -
_ _ _
_
_ _ _
_ _ _
_ _
_ - _
_ _ _
_ _ _
_ _ _
_ - -
_
_ _
_ - _
- -
_
-------
Table G-l (continued). WESTERN GOAL COMPOSITION & PHYSICAL PROPERTIES
un
t—'
oo
County
Coal
field
or
town
Mine
Proxijnate
analysis , *
1
Date
of
analy-
Name sis Seam
4}
Volatile
a
c
1
C
a
to
<
Wyoming
Carbon
n
n
tt
n
n
n
»
n
n
n
n
n
n
n
n
tt
It
n
n
it
n
n
rt
tt
Harma
n
n
it
H
it
it
n
tt
n
it
tr
tr
ii
n
ti
n
n
Iron
n
11
it
n
n
H
Hanna No. b
n
it
n
11
n
F.D. McMlllen
n
n
J. Johnson
n
it
Charles West
n
tt
Coulter
n
tr
Kronkheit
tt
n
11
it
n
Perm-doming
Hanna
No. 2
n
TI
If
n
n
Unnamed
n
n
11
n
ii
n
tt
«
it
n
H
tt
ft
n
it
n
n
n
11.2
_
-
12.7
-
—
17.2
-
—
9.5
_•
_
17.0
_
—
15.3
-
-
13.9
-
—
12-3
-
18.1
10.6
15.7
17.9
11.2
17.2
50.1
33.2
10.1
12.1
39.3
33.1
17.9
31.5
11.6
11.8
33.6
39.7
12.6
36.2
12.0
11.2
36.1
11.1
13.7
31.5
11.1
19.7
52.1
40.6
16.6
49.6
15.8
55.3
57.9
42.8
17.3
52.1
42.5
51.2
55.2
45.1
53.6
57.1
15.7
53.1
55.8
46.4
53.0
56.3
43-1
1.1
1.6
-
5-5
6.2
_
3-8
4.6
-
8.1
9.3
6.0
7-2
5.7
6.7
-
1.2
4.9
5.2
5-9
—
3-7
Sulflir
Ultijnate
analysis , %
Hydrogen
c
Nitrogen
*
o
Btu
as Btu
received dry
Ash
softening Free Hardgrove
tempera- swelling grindability
ture,,?0 Index index
(continued)
.3
-3
.1
.5
.6
.6
.8
1.0
1.0
.5
.6
.6
1.7
2.1
2.2
2.3
2.7
2.9
.1
.1
.4
.3
.1
.4
.3
6.0
5.1
5.6
6.0
5-3
5.6
6.2
5-2
5.5
6.0
5.1
6.0
6.1
5-1
5-5
6.0
5.1
5-5
5-5
1.5
4.8
5-5
4.8
5.1
5-5
65.8
71.1
77-7
61.8
70.7
75.5
59.4
71.8
75.2
62.8
69.3
76.5
55.9
67.4
72.7
57.0
67.3
72.2
60.0
69-7
72-3
61.7
70.3
74.7
53.9
.9
1.0
1.1
1.1
1.3
1.1
1.1
1.7
1.7
1.1
1.2
1.1
1.3
1.6
1.7
1.6
1.9
2.1
1.14
1.6
.7
1.3
1.5
1.6
1.3
22.9
11.6
15-2
25.1
15-9
16.9
28.1
15.7
16.6
21.2
11.2
15.5
29.0
16.6
17.9
27.1
16.3
17.3
28.5
18.9
19.9
26.0
17.1
18.2
35.3
11,160
12,910
13,510
11,000
12,600
13,100
10,100
12,560
13,170
11,160
12,330
13,600
10,010
12,100
13,050
10,250
12,100
12,970
10,520
12,220
12,850
10,670
12,160
12,920
9,130
2,110
— —
_ _ *
a, *iio
_ _
2,240
— -
2,280
— -
2,570
— -
_ -
_
_ -
-
_ _
_ _
_ _
_
_
-
_
_
_
_
—
_
_
„
_
_
_
_
_
„
_
_
_
_
_
_
^
„
_
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
vo
Coal
field
or
County town
Carl
xm Iron
n
n
n
n
Medicine Bow
n
n
n
tl
n
Rawlins
n
n
it
n
M
n
tt
n
11 Walcott
II It
II II
Converse Big Jfoddy
Mine
Proximate
analysis, *
1
Date £
of ra
analy- -g
Name sls Seam S
Penn-lfyoming
MiUer
II
tt
Unnamed
" 15.5
n _
it _
Cliftm-Wissler " 13.3
n « _
n
Nelson
n
n
Dillon
11
n
Nebraska
n
n
Robertson
Opening
n
n
J. P. Ryan
Big Muddy
n _
" 16.8
it _
" 10.1
n _
w _
" 19.2
n _
n _
13.6
It _
tt _
11.4
tl _
I) _
Upper 25.1
Ruddy
0)
i-t
•H
1
42.3
44.3
37-2
42.8
44.6
33.6
38.3
43.2
33.4
40.2
41.8
33.9
37-7
41.6
36.5
45.1
47.3
34.6
40.0
44.5
S!
39.5
32.0
a
0
1
e
53-1
55-7
44.8
53-0
55.4
44.2
50.9
56.8
46.6
56.0
58.2
47.6
52.9
58.4
41.5
50.2
52.7
43.1
49.9
55.5
51.7
58.4
60.5
38.1
1
I
Ultimate
analysis , %
I
I
Vfyomlng (continued)
4.6 .3 4.3 66.0
.1 1.5 69.2
3.5 .8 5.6 58.9
4.2 .9 4.6 69.6
_
8.9
10.3
3.2
3.8
8.4
9.4
3.8
4.7
8.7
10.7
3.1
3.5
4.8
1.0
l.i
1.3
1.4
.2
.2
.3
'.6
.6
.3
.4
.4
1.1
1.7
1.9
.6
.7
.8
.7
4.8
5.5
4.7
5.2
5-9
4.8
5.0
5.2
4.5
5.0
5-7
4.5
4.7
5.5
4.7
5-2
5.6
4.9
5.1
6.3
72.7
57-3
66.1
73.6
59-0
72.1
74.9
63.8
70.9
78.3
58.9
72.9
76.5
58.8
68.1
76.7
65.5
73-9
76.5
52.8
i
1.6
1.7
1.4
1.7
1.8
1.2
1.4
1.6
.8
1.0
1.0
1.3
1.5
1.6
1.3
1.7
1.7
.9
1.0
1.2
2.2
2.4
2.5
1.2
1
S
23.2
24.2
29.8
19.0
19-7
26.0
16.2
18.2
30.0
18.1
18.8
20.8
13.1
14.5
30.0
15.8
16.7
24.7
11.4
16.0
23-0
14.6
15-1
34.2
Ash
Btu softening Free
as Btu tempera- swelling
received dry ture,F° index
11,190 - - -
11,720 -
10,520 - - -
12,440 - - -
12,920 - - -
10,040 - 2,450
11,580 - - -
12,910 - - -
10,320 . - 2,450
12,410 - - -
12,900 - - -
11,010 - - -
12,250 - - ~
13,520 - - -
9,720 - - -
12,030 -
12,620 -
10,340 11,967
11,970 -
ll|430 - 2,260
12,900 - - -
13,360 - - -
8,970 - 2,240
Hardgrove
grindatility
index
_
~
-
~
~
~
-
-
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
rv>
o
Coal
field
or
County town
Converse Big Muddy
n n
n n
n it
it It
" Glenrock
n n
tt n
tt tt
tt tt
tt it
it tt
tt tr
n ti
" Inez
fi ri
n u
11 Jjost Spring
it n
n n
it n
it ti
Mine
Proximate
analysis, ?
1
Date
of
analy-
Naroe sis Seam
Big Mu3<3y
n
11
n
tt
Fairview
«
n
Slenrock No. 2
it
n
Country Bank
n
n
Inez
"
"
Onyon
M
tt
Rosin
"
Upper
Big
Muddy
n
Lower
Big
Muddy
tt
n
Unnamed
n
n
Qlenrock
ti
it
Unnamed
"
"
n
"
tt
Unnamed
tt
n
f!
"
Moisture
-
_
23.5
_
_
22.8
_
_
19.9
_
28.1
_
-
27.9
-
-
27.9
-
_
27.7
-
|H
«H
12.7
15.6
34-3
11.9
49.1
31.7
11.9
18.1
19.3
61.5
70.9
31.6
41.0
17.0
32.1
11.5
50.3
27.7
37.6
42.4
26.7
36.9
a
0
1
fi
.c
Wyoming
50.9 6.U
54.4
35.2
15.9
50.6
37.0
17.0
51.6
20.2
25-3
29.1
35.7
49.6
53.0
31.7
11.0
19-7
36.7
50.9
57.6
35.6
49.?
-
7-0
9.2
5.5
7.2
10.6
13.2
4.6
6.4
-
8.3
11.5
8.3
11-5
10.0
13.8
Sulfur
Ultimte
analysis , %
Hydrogen
(continued)
1.0 1.7
1.0
.6
.8
.9
.7
.9
1.0
.7
.9
1.0
.5
.6
.7
.7
1.0
1.1
.9
1.2
1.4
1.0
1.4
5-0
5.9
4.2
4.7
6.1
4.6
1.9
5.4
4.0
4.6
6.6
1.8
5.1
6.1
1.5
5.1
6.3
4.1
4.9
6.3
Carbon
70.5
75.3
51-2
66.9
73.6
51.7
70.8
76.2
52.0
61.9
71.8
18.3
67.2
71.8
15-3
62.9
61.1
47-5
65-9
74.4
45-8
53-2
Nitrogen
1.6
1-7
1.0
1.3
1.4
1.0
1.3
1.4
.6
.8
.9
.7
1.0
1.0
.7
1.0
1.1
.8
1.1
1.3
.7
.9
i
I?
15.8
17.0
34.3
17.5
19. if
32.0
15-2
16.5
30-7
16.2
18.7
39.3
20.0
21.4
38.6
19-1
21.6
36. a
15.9
18.0
36.2
16. j
Btu
as
received
11,970
12,780
9,560
11,180
12,310
9,270
12,000
12,930
8,730
10,900
12,560
8.350
11,610
12,110
7,790
10 ,800
12,210
7,930
11,003
12,130
7,810
10,790
Ash
softening Free
Btu tenpera- swelling
dry ture,P° index
_
_ _ _
2,100
_ _
_ _
2,210
_ _
_ _
_ _ _
_ _
_ _
2,360
_
_ _
2,180
_
_
2,010
-
_
2,170-
_
Hardgrove
grindability
index
-
_
-
-
_
-
-
_
_
-
_
-
-
-
-
-
-
-
-
-
.
-
-------
Table G-l (continued}. WSTERN COAL COMPOSITION & PHYSICAL PROPERTIES
Ul
to
County
Coal
field
or*
town
Mine
Proximate
analysis , *
S
jO
Date |
of 5
analy- -H
Nane sis Seam £
Volatile
1
1
en
Wyoming
Converse
Crook
n
n
tf
ti
n
n
M
ti
FreEoont
n
n
it
n
n
n
ti
n
tf
ti
ti
n
n
ti
lost Spring Rosin
Aladdin
n
n
tr
n
n
Sundance
n
It
Hidson
n
n
n
n
n
n
n
ti
it
n
tf
it
IT
tr
Stilwell
n
n
"
n
n
Belche
n
n
Hlckey
tt
n
Indian
H
n
n
it
n
n
ti
ti
McKlnley
"
"
Unnamed
n
n
n
n
11
it
if
n
"
11
n
n
n
n
it
n
n
it
tt
11
«
ti
n
it
17.8
-
-
14.0
_
_
19.3
-
23.1
_
_
21.3
_
21.1
_
_
20.9
_
_
•20.7
-
42.8
37.6
45.7
48.7
36.8
42.8
49.0
35.4
13.8
50.8
33.1
43.0
15.5
32.8
41.7
43.4
31.4
39-7
42.9
32.0
40.4
42.4
33-9
42.8
47.3
57.2
39-5
48.1
51-3
38.3
11.5
51.0
31.2
42.5
49.2
39-6
51.5
51.5
42.7
54-3
56.6
41.7
52.9
57.1
43.4
54.9
57.6
37.8
47.6
52.7
_
5.1
6.2
-
10.9
12.7
11.1
13-7
-
1.2
5.5
3-2
4.0
_
5.8
7.4
3-7
1.7
7^6
9.6
!
Ultimate
analysis, %
Hydrogen
i
•H
z
1
Btu
as Btu
received dry
Ash
softening Free
tenpera- swelling
ture.F0 Index
Hardgrove
grlnaablllty
Index
(continued)
1.7
5-6
6.8
7-3
5.0
5.8
6.6
4.4
5.4
6.3
.7
-9
1.0
.9
1.1
1.2
.5
.6
.7
.5
.6
.6
1,2
1.5
1.7
5.1
5-9
4.8
5.2
6.0
5.2
5-9
5-9
4.7
5.4
6.2
4.8
5.0
6.1
4.8
5.0
6.2
4.9
5.3
6.2
4.9
5-2
7.2
4.9
5.4
73-4
55.7
67.7
72.2
55.9
65.1
71.6
51.0
63.3
73-3
55.1
71.7
75.8
55.9
71.0
74.0
51.3
68.9
74.3
56.7
71.7
75.2
53-9
68.0
75-2
1.1
.9
1.1
1.2
.9
1.0
1.1
.8
.9
1.1
1.4
1.8
1.9
.8
1.0
1.0
1.2
1.5
1.7
1.2
1.6
1.6
1.2
1.5
1.6
18.7
26.8
13.1
14.1
21.3
10.2
11.8
26.8
12.0
13.9
32.4
15.3
16.3
33-1
18.1
18.8
32.0
16.7
18,0
31.7
16.5
17.4
29.9
14.5
16.1
12,520
10,110
12,290
13,100
10,330
12,020
13,770
9,200 '
11,400
13,220
9,510
12,360
13,080
9.780
12,420
12,940
9,160 . -
11,990
12,940
9,780
12,360
12,970
9,420
11,800
13,140
_ _.
_ _
- -
- -
-
- -
-
2,150
-
-
2,150
- -
- -
-
-
-
-
-
-
2,240
-
-
-
-
-
—
_
-
-
-
-
-
-
-
-
_
—
—
—
-
-
-
-
-
-
-
-
-
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
ui
County
Freocmt
n
it
IT
Tl
n
M
M
It
II
II
Hot Springs
n
n
n
ti
ti
Coal
field
or
town
Hudson
IT
ft
tr
TI
n
n
n
n
n
Tl
n
Lander
it
H
liberty
Rongis
fi
n
Crosby
it
n
n
n
n
Mine
Proximate
analysis , "<•
1
Date
of
analy-
Name sis seam
Pope
mt
Big
jsiaNo. 1
-tell
Horn
Speyer
Prospect
n
n
Crosby or
Big Horn
n
it
n
w
K
0)
-------
Table G-l (continued1). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
ro
County
Hot Barings
Coal
field
or
town
Crosby
Mine
Name
Crosby or
Proximate
analysis , %
g
Date
of
analy-
sis Seam
Qebo
£ £ 1
£ 4J TJ
^H rH &
£ £ £
15-3 36.5 44.3
1
Wyoming
3-9
§
rH
Ulttoatt-
analysis, %
g
g 8
if. 1
g
c?
i
i
i
Btu
as Stu
received dry
Ash
softening Free
tenpera- swelling
ture,P° index
Hartgrove
grlndlabllity
index
(continued)
.6
6.1 63.2
1.4
24.8
11,160
_
_
Big Ham
ft
tl
n
n
rt
n
n
TI
n
n
n
n
TI
n
n
n
il
TI
ti
ti
11
TI
ft
n
n
n
n
ft
n
Gebo
n
n
it
"
n
ti
tt
it
IT
IT
It
IT
IT
n
it
ti
n
Kirby
n
n
n
n
it
Gebo
n
n
n
TI
IT
tt
n
n
n
11
n
it
ti
tt
it
it
IP
MacPherson
ft
IT
n
n
n
n
n
n
n
n
n
n
n
n
n
IT
n
n
it
it
n
n
il
Unnamed
- 43.0 52.4
- 45.1 54-9
14.7 33.6 18.1
- 39.4 56.4
- 11.2 58.8
17.0 35.5 45.2
- 42.8 54.4
- 11.1 55.9
15.9 33-0 17-4
- 39.2 56.4
- 41.1 58.9
16.9 33.1 46.0
- 39-8 55-3
- 41.8 58.2
14.5 36.3 45.0
- 42.5 52.6
- 41.7 55-3
13-8 35.5 45.5
- 41.2 52.8
- 43.9 56.1
12.9 34.5 46.9
- 39.6 -53.8
- 12.1 57.6
10.9 35.4 50.7
4.6
-
3.6
4.2
-
2.3
2.8
-
3-7
4.1
-
4.0
1.9
4.2
4.9
5.2
6.0
_
5.7
6.6
_
3.0
.7
.7
.7
.8
.9
.4
.5
.5
.6
.7
.7
.6
.8
.8
.6
.7
.7
.6
.7
.7
.5
.6
.6
.6
5.2 74.6
5.5 78.2
6.1 61.1
5-3 75.1
5-5 78.1
6.0 62.2
4.9 75.0
5.1 77.2
6.1 62.0
5-1 73-7
5-4 77.2
6.1 61.1
5.0 71.0
5-3 77.8
6.0 63.5
5.2 71.2
5.4 78.1
5.7 61.4
1.9 74.7
5-2 79-5
6.1 52.6
5-3 71.9
5.7 77.0
5.7 66.1
1.7
1.8
1.4
1.7
1.7
1.2
1.3
1.1
1-3
1.5
1.6
1.3
1.6
1.7
1.1
1.6
1-7
1-3
1.5
1.6
1.4
1.6
1.7
1.1
13.2
13.8
21.1
12.9
13-5
28.0
15.5
15.8
26.3
11.6
15.1
26.6
13.7
24 .'3
13.4
14.1
22.8
12.2
13.0
23.7
11.0
15.0
23.2
13,170
13,810
11,110
13,380
13,970
10,990
13,250
13,630
10,980
13,050
13,660
10,800
13,000
13,660
11,210
13,140
13,820
11,210
13,010
13,810
11,280
12,950
13,860
11,410
- -
- -
-
-
- -
-
-
-
-
-
- -
-
-
-
-
- -
-
-
-
-
2,240
- -
-
2,160
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Lucerne
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
ui
M
-Cr
Coal
field
or
County town
Hat Springs Kirby
Lucerne
"
n ii
n n
n n
Hot Springs Ihennopolis
tt ii
tt it
n tt
n tt
it it
Johnson Buffalo
tt n
it tt
« ti
tt tt
n ii
n • n
Mine
Date
of
analy-
Narae sis
MacPherson
n
Price & Jones
n
"
Eades
n
n
Cowboy
ii
"
M & M
n
tt
n
TI
tt
Mitchell
1
'
I
1
I
Munkre
Proximate
analysis , t
1
Seam
Unnamed
"
Tt
It
"
n
ti
tt
tt
11
ti
No. 2
n
"
Tt
TI
11
Unnamed
n
n
M
n
n
it
£
to
«H
£
_
_
16.1
-
-
12.1
-
-
19.6
-
—
10.4
-
-
11.3
-
-
29.1
-
-
26.8
-
-
28.0
OJ
«H
1
30.7
41.1
33.0
39.3
40.7
32.6
37.1
39.8
31.2
38.8
40.5
35-5
39.6
45.8
36.4
4l.l
45.4
29.1
41.0
45.6
32.8
44.8
54.0
29.8
1
O
1
•H
ft.
56.9
58.9
48.1
57.4
59.3
49.2
55.9
60.2
45.8
57.0
59.5
41.9
46.8
54.2
43.8
49.4
54.6
34.0
48.8
54.4
27-9
38.2
46.0
32.7
1
Vfycndng
3.4
_
2.8
3.4
-
6.1
7.0
3.4
4.2
_
12.2
13.6
_
8.5
9-5
7.2
10.2
_
12.5
17.0
_
9.5
H
Ultimate
analysis , %
c
i 1
c
•P
1
Btu
as
received
Ash
softening
Btu tenpera-
dry ture.F0
Free Hardgrove
swelling grindabllity
index Index
(continued)
.7
.7
.5
.6
.6
.9
1.0
1.1
.9
1.1
1.2
1.3
1.4
1.6
1.7
1.9
2.2
.4
.6
.6
.6
.9
1.1
.7
5.0 74.2
5.2 76.8
6.0 62.5
5-0 74.5
5.2 77.1
5.4 63.8
4.6 72.5
5.0 77.9
6.4 59.2
5.3 73.6
5.5 76.8
5.5 60.4
4.8 67.4
5.6 78.0
5.7 61.9
5.0 69.7
5.5 77.1
6.5 44.6
4.7 62.9
5.2 70.0
6.0 42.7
4.2 58.3
5-0 70.3
6.4 43.8
1.6
1.7
1.0
1.2
1.3
1.0
1.1
1.2
1.3
1.6
1.7
1.2
1.3
1.5
1.2
1.4
1.5
.5
.7
.8
.6
.8
1.0
.6
15.1
15.6
27.2
15.3
15.8
22.8
13.8
14.8
28.8
14.2
14.8
19.4
11.5
13.3
21.0
12.5
13.7
40.8
20.9
23.4
37.6
18.8
22.6
39.0
12,840
13,280
11,210
13,360
13,830
11,250
12,800
13,750
10,440
12,990
13,560
10,540
11,770
13,620
11,070
12,480
13,790
7,630
10,750
11,970
7,340
10,030
12,090
7,580
_
_ _
_ _
_ _
_ _
_ _
_ _
2,080
_ _
2,680
_ —
2,^0
— _
-
_
_ _
_ _
_ _
_ _
_ _
-
_
_ _
— _
— —
_ _
— —
_ _
_ _
. _ _
_ _
_
_ _
„ _
- _
_ _
-
_
_ _
_ _
— _
_ _
- —
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
ui
r\j
Ul
Coal
field
or
County town
Johnson Buffalo
n
Caster
n
Hamilton
-
Lincoln Cumberland
n ii
n "
" Diaraond-
vllle
h «
n n
" Elkol
n "
n n
n it
ii it
Mine
Date
of
analy-
Nams sls
(takre
n
Puggsley
n
n
Prospect
n
Surface
Prospect
n
tt
Cunfcerland
No. 1
n
11
No. 1
n
tt
Elkol
ft
n
tf
Proximate
analysis , *
•P
Seam
Unnamed
it
H
n
it
n
n
n
Healy
n
Krenn
merer
n
n
11
»
ELcol
n
n
ii
n
|
3
£
23.5
16.8
28.4
-
6.8
5.1
21.5
20.6
tt>
•ri
I
41.3
47.6
35.7
46.6
49.9
31.4
37.8
46.1
31.1
43.4
47.7
39.8
42.7
45.6
40.5
52.7
44.9
35.3
44.9
46 %6
35-1
44.2
a
o
a
45.5
52.4
35.6
46.6
50.1
36.8
44.2
53-9
34.0
47.5
52.3
47.4
50.9
54.4
49.8
52.4
55-1
40.4
51.5
53.4
39.8
50.2
1
Wyoming
13.2
5.2
6.8
15.0
18.0
6.5
9.1
6.0
6.4
4.6
4.9
278
3-6
4.5
5.6
•3
Ultimate
analysis, <
e
p o
!H
c
I
1
Btu
as Btu
received dry
Ash
softening Free
tempera- swelling
ture.F0 Index
Hardgrove
grindability
Index
(continued)
1.0
1.2
'.6
.7
1.5
1.9
2.3
.7
1.0
1.1
.4
.5
.5
.5
.5
'.6
.8
.8
.6
.7
4.6 60.9
5.3 70.1
6.5 51-2
5.1 67.0
5-5 71.8
5-5 58.9
4.4 58.8
5.4 71-8
6.4 46.2
4.5 64.6
5.0 71.0
5.6 69.0
5.2 74.0
5-5 79.1
5.6 73-0
5.3 76.9
5.6 80.8
6.4 58.4
5.1 74.3
5.3 77-1
6.3 56.3
5.0 72.2
.8
1.0
.7
.9
1.0
1.0
1.2
1.5
.7
1.0
1.1
1.1
1.2
1.3
1.2
1.2
1.3
.8
1.0
1.0
.8
'.0
19.5
22.4
35-9
19.6
21.0
28.1
15.7
91.0
39-5
19.8
21.8
17-9
12.7
13.6
15.1
11.2
11.8
31.0
15.2
15.8
30.5
15.5
10,530
12,120
9,050
11,820
12,680
8,480
10,200
12,430
8,000
11,170
12,280
12,270
13,160
14, 060
12,960
13,660
14,360
10,260
13,060
13,550
10,100
12,720
2,210
2,500
-
— "
-
2,400
2,380
-
-
"
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
VJl
ro
County
Lincoln
it
„
n
II
it
n
tt
tt
"
it
n
tt
• ti
"
n
n
Coal
field
or
town
Elkol
It
tt
tt
tl
tt
n
Oakley
ti
Frontier
"
n
n
"
it
Mine
Name
Elkol
tt
tt
tt
It
Proxiirate
analysis , *
I
Date
of
analy-
sis Seam
Elkol
"
n
"
"
n
"
W II
Sneddon No. 1 Spring
n
Kenmerer
No. 1
tt
it
ti
"
ti
vaiiey
n
ti
Lower or
"A"
n
Kenmerer
No. 1
II
tt
n
"
"
ii
g
41
in
•H
-
21.0
—
20.8
-
-
21.2
-
eT?
-
5-9
-
5.9
-
-
. 5-7
-
—
6.3
H
Volati
46.8
35.1
44.4
46.3
35.4
44.6
46.5
34.1
34.3
44.9
33.5
35.9
44.2
39.5
42.0
43.6
37.6
39.9
43.14
37.7
40.0
42.4
39.0
1
o
•H
fc
53.2
40.7
51.6
53-7
40.6
51.3
53-5
41.8
53.0
55.1
42.3
45.4
55.8
50.9
54.1
56.4
49.0
52.1
56.6
51-3
54.4
57.6
51.2
EQ
Wyoming
_
3.2
4.0
3.2
4.1
-
2.9
3-7
17-5
18.7
3-7
3.9
7.5
8.0
-
5-3
5.6
—
3.5
Sulfur
Ultimate
analysis, %
c
ft ,O
c
4>
t
8tu
as Btu
received dry
Ash
softening Free Hardgrove
tempera- swelling grindability
ture,F° index index
(continued)
.8
.6
.8
.8
.7
.9
.9
.6
.8
.8
.7
.7
.9
1.1
1.1
1.2
1.4
1.5
1.6
1.4
1.5
1.6
.9
5.3 76.5
6.2 57.1
4.9 72.3
5.1 75.3
6.3 57.8
5.0 73-0
5.2 76.1
6.6 58.2
5.4 73.9
. 5.6 76.7
5.1 61.7
4.6 66.1
5-7 81.3
5.6 73.0
5-2 77-5
5.4 80.6
5.3 68.5
4.9 72.8
5.4 79.1
5.5 70.6
5.1 74.8
5.4 79.3
5.5 72.0
1.0
.9
1.1
1.2
.9
1.1
1.2
.9
1.2
1.2
1.1
1.1
1.4
1.0
1.2
1.2
1.2
1.1
1.2
1.0
1.1
1.1
1.0
16.4
32.0
16.9
17.6
31.1
15.9
16.6
30.8
15.0
15.7
13.9
8.8
10.7
15.6
11.1
11.6
16.2
11.7
12.7
16.2
11.9
12.6
17.1
13,470
9,900
12,520
13,050
10,080
12,730
13,270
10,060
12,770
13,260
10,870
11,650
14,330
12,780
13,580
14,130
12,370
13,140
14,280
12,580
13,330 14,135
14,130
12,780
2,420
2,300
2,180
2,390
-
-
~
2,060
_ _
2,060
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
v_n
ro
-4
Mine
Proximate
analysis , '•
1
Coal Date £
field of |
or analy- -H
County town Name sis Seam E
Lincoln Frontier Kemnerer No. 1
it n
n n
H n
It it
n n
it n
n n ti
« " Willow Creek
Prospect
n "
n n
n n
n n
n "
it It
it n
n n n
" Kenmerer Pitzpatrlck
n n n
tl tl II
" Merna Prospect
It n It
it tt n
" Stanley "
Kemnerer
No. 1
n
n
it
n
it
tt
tt
Willow
Creek
n
n
Unnamed
it
tt
n
it
n
Sprlj-ig
Valley
n
tt
Unnamed
it
n
ii
-
_
5.6
_
5.2
_
4.0
_
6.9
_
18.1
_
7.1
_
_
9-6
_
27.6
Volatile
11.7
13-3
37.1
39.7
41.1
38.7
10.8
11.9
36.2
37.7
39.6
38.0
10.9
12.5
37.1
15.3
46.7
35.2
37.9
40.9
38.7
12.8
15.2
31.0
i
I
e
I
Wyoming
51.5 3-8
56.7
17.5
50.2
55-9
17.5
50.2
55.1
55-0
57.3
60.1
51.1
55.3
57-5
12.3
51.6
53-3
50.8
51.7
59.1
16.9
51.9
51.8
31.7
_
9.5
10.1
_
8.6
9.0
1.8
5.0
3~6
3.8
2.5
3.1
6.9
7.1
4.8
5-3
9.7
Sulfur
Ultimate
analysis , <
i
(continued)
1.0 5.2
1.0
1.4
1.5
1.7
1.4
1.5
1.6
.8
.8
.8
1.8
1.9
2.0
2.0
2.4
2.5
.4
.5
.5
.3
.4
.4
.9
5.4
5.5
5.2
5.8
5.5
5.2
5-7
5.2
1.9
5.2
5.3
4.9
5.1
6.3
5.2
5.4
5.5
5.1
5.5
5.5
4.9
5.2
5.7
I
76.8
79.8
67.4
11.4
79-1
68.1
71.8
78.9
76.0
70.2
83.3
70.6
75.8
78.8
60.0
73.3
75.6
70.6
76.0
82.1
66.9
74.0
78.2
40.5
Nitrogen
1.1
1.1
.9
1.0
l.l
1.1
1.2
1.3
1.3
1.4
1.4
1.0
1.1
1.1
1.1
1.3
1.3
1.3
1.4
1.5
1.3
1.5
1.6
1.1
1
12.1
12.7
15-3
10.8
12.0
15.3
11.3
12.5
11.9
8.7
9-3
17.7
12.5
13.0
28.1
11.7
15.2
15.3
9.6
10.1
21.2
3.9
14.6
42.1
Btu
as Btu
received dry
13,640
14,170
12,000
12,710
11,110
12,210
12,880
14,150
13,500
14,060
11,790
12,690
13,630
14,170
10,630
12,970
13,380
12,470
13,420
14,490
12,000
13,270
14,010
6,600
Ash
softening Free
tempera- swelling
ture.F0 index
-
-
2,170
— ~
— -
2,190
— —
-
— -
-
— -
— ~
— -
— ~
1,920
— ~
_ -
2,390
— -
— —
-
— ~
-
Hardgrove
grindability
Index
-
—
—
~~
~
~"
~
™
*"
-
~
~
~
—
—
~
~
—
~
~
-
~
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
oo
County
Coal
field
or
town
Mine
Date g
of £
analy- 43
Name sis seam S
Proximate
analysis , %
I
I Volatile
1
O
1
1
rH
Ultimate
analysis, %
Hydrogen
|
\
!
Ash
Btu softening Free
as Btu tempera- swelling
received dry ture,F° index
Hardgrove
grindability
index
Wyoming (continued)
Lincoln
it
i
t
n
"
"
"
it
n
Stanley
Sublet
"
n
"
"
"
1
n
n
"
"
Susie
n
Prospect Unnamed - •
Kemnerer No. 6 Kemnerer 3.9
It 11
It II
" " 3-9
It It
11 II
" " 7.1
" " _
n n _
6.3
II Tl
11 II
No. 5 Willow 3.6
Creek or
No. 5
" " —
II II
" " 3.8
ii it _
" —
Kenmerer No. 4 Kenroerer 6.6
No. 1 •
n n
—
42.8
49.4
40.1
41.7
45.0
40.3
42.0
45.5
38.7
41.6
43.4
39.5
42.1
44.5
38.4
39.9
42.3
37.1
38.6
41.2
39-2
42.0
45.1
43.8
50.6
49.0
51.0
55.0
48.4
50.3
54.5
50.4
54.3
56.6
49-3
52.7
55.5
52.5
54.4
57-7
52.9
54.9
58.8
47.7
51.1
54.9
13.4
7.0
7.3
-
7.4
7.4
-
3.8
4.1
-
4.9
5.2
_
5.5
5.7
-
6.2
6.5
_
6.5
6.9
-
1.2
1.4
.6
.6
.7
-.7
.8
.8
.6
.6
.6
.5
.5
.5
1.0
1.0
1.1
.9
.9
1.0
1.4
1.5
1.6
3.6
4.2
5-5
5.3
5.7
5.5
5.3
5.7
5-7
5.3
5-5
5.6
5.3
5.6
5.3
5-1
5.4
5.5
5-2
5.6
5-3
4.9
5.2
55.9
64.5
72.2
75.2
81.0
71.0
74.8
81.0
71.8
77.3
80.6
71-9
76.8
81.0
74.5
77.2
81.9
73.7
76.6
81.9
69.6
74.4
80.0
1.5
1.7
1.2
1.3
1.1
1.3
1.4
1.5
1.3
1.4
1.5
1.3
1.4
1.5
1-3
1.4
1.4
1-3
1.4
1.5
1.3
1.3
1.4
24.4
28.2
13-5
10.3
11.2
13.2
10.0
11.0
16.8
11.3
11.8
15.8
10.8
11.4
12.4
9.6
10.2
12.4
9.4
10.0
15.9
11.0
11.8
9,110 -
10,520 -
12,800 -
13,420 -
14,470 - - -
12,810 -
13,460 -
14,470
12,750 - 2,250
13,720 -
14,310 - - -
12,680 - 2,170
13,530 -
14,280 -
13,310 -
13,810 - - -
14,640 -
13,050 -
13,560 -
14,490 -
12,360 -
13,230 -
14,210 -
-
-
_
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
VJ1
ro
vo
Proximate
analysis, *
County
Lincoln
It
n
n
n
Park
tl
n
n
n
n
n
n
ti
tt
n
n
n
n
n
ti
Coal
field
or
town
Viola
n
tt
n
n
Cody
n
n
n
n
Garland
n
Meeteetse
Mine
Date
of
analy-
Name sis
Prospect
Cody
Allison
tt
n
Honeysett
n
Graybull or
Erskine
tt
It
Black Diamond
tt
n
Orr
n
Seam
Unnamed
n
Willow
Creek
n
n
Unnamed
H
n
n
n
n
n .
n
n
«
tf
n
n
n
n
n
11
n
a) g>
§ T\
5 4J
3 3
£ £
22.1 35.8
- 16.1
- 17.9
1.7 31.7
- 37.6
- 10.1
17.3 11-3
- 37.9
- 10.6
13-8 35.0
- 10.6
- 17.1
13.3 29.2
- 33-7
36 6
15-0 32.5
- 38.3
- 13.8
17.7 27.3
- 33.1
- 36.5
16.1 35.1
- 11.9
- 16.3
|
O
1
£
38.8
50.0
52.1
53-3
57.7
60.6
15.9
55-5
59.1
39.3
15.6
52.9
50.8
58.5
63.1
11.7
18.9
56.2
17.1
57.7
63.5
18.8
18.6
53-7
1
Wyoming
3-0
3-9
1.3
1.7
5.5
6.6
U.9
13.8
6?7
7.8
10.8
12.8
7^6
9.2
s~.o
9.5
£
Ultimate
analysis > J
! i
1
!
Btu
as Btu
received dry
Ash
softening
tenpera-
ture,F°
Free
swelling
index
Hardgrove
grindability
index
(continued)
1.9
2.1
2.5
.5
.5
.5
!i
.5
.6
.7
.9
.8
1.0
1.1
1.1
1.3
1.1
.2
.2
.2
'.6
.7
6.1 51.6
5-0 70.3
5.2 73.2
5-3 71.5
1.9 77-5
5.1 81.3
5.6 59-2
1.5 71.5
1.8 76.6
5.1 52.3
1.5 61.3
5.2 71.1
5.6 62.0
1.7 71.5
5.7 77.5
5.7 55.1
1.7 65.2
5.1 71.8
5.1 57.1
1.1 69-3
1-.5 76.1
5-9 51.1
1.9 61.5
5-1 71.3
.9
1.2
1.2
1.1
1.2
1.3
.9
1.0
1.1
1.0
1.2
1.4
1.1
1.3
1.1
1.1
1.3
1.5
.8
1.0
1.1
.9
1.1
1.2
33.2
17.2
17.9
17.3
11.2
U.8
28.1
16.0
16.0
28.3
21.5
21.1
23.8
13.7
11.9
25.9
11.7
16.9
28.9
16.2
17.8
30.6
19.1
21.1
9,160
12,130
12,920
12,690
13,760
11,430
10,060
12,160
13,020
9,270
10,750
12,170
10,810
12,530
13,590
9,930
11,680
13,390
9,690
11,770
12,960
9,320
11,110
12,280
-
-
-
2,090
"
-
-
-
-
-
-
-
-
-
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
uo
o
County
Coal
field
or
town
Mine
Proximate
analysis » ^
I
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
ui
uo
Proximate
Mine
Coal Date §
field of 3
or analy- 2
County town Name sis Seam S
analysis
s
rH O
S T5
rt S
> fc
. '
x:
2.
Wyoming
Sheridan Acme Acne No. 2 Carney &
Masters
« n if n 24 7
IT n if n _
ff ft ff w _
" Carney- Model Carney 25.9
vllle
"
"
11
»
"
"
"
"
«
"
"
«
n
»
"
n
1
"
Can
If _
n _
ley No. 1 " a2.8
rr _
11 -
" 21.5
" _
ii —
25.3
n __
ti _
« 25.3
H —
« 24.5
n _
n _
Carney No. 2 " 25.8
n II n _
13-5 56.5
31.8 39.8
12.1 53.0
11.3 55.7
29.1 37.8
39.7 50.9
43.8 56.2
34.2 39.6
44.3 51.2
46.4 53.6
35.1 39.0
44.7 49.7
17-3 52.7
32.9 39.0
14.1 52.2
15.8 51.2
30.7 10.3
11.2 53.9
13-3 56.7
30.4 41.9
40.2 55.5
42.0 58.0
29.fi 11.2
40.1 55.6
_
3.7
1.9
-
6.9
9.1
_
3-1
1-5
1.4
5.6
_
2.8
3.7
3-7
1.9
_
3.2
4.3
3-2
1.3
1
S
Ultimate
analysis,
g
P 8
•3 fj
°
%
c
S?
s
z
1
5
6
Btu
as
received
Ash
softening Free
Btu tenpera- swelling
tiry ture.F0 index
Hardgrove
grfndability
index
(continued)
.5
.4
.5
.5
.3
.5
.5
.4
.5
.5
.8
1.0
1.0
.3
,4
.5
.4
.6
.6
.3
.4
.4
.3
.4
5-3 73.3
6.5 52.3
5.0 69.1
5.2 73.0
6.2 51.0
4.5 68.8
5.0 75.9
6.0 51.9
4.5 71.1
4.7 74.1
5.8 50.9
4.4 69.9
1.6 74.0
3-6 53-5
4.6 71.6
4.8 74.3
6.3 53-5
4.7 71.6
5.0 75.3
6.2 53.7
4.6 71.1
4.8 74.3
6.3 53-1
4.7 72.0
1.3
1.2
1.6
1.7
1.0
1.4
1.5
1.0
1.3
1.4
1.0
1.3
1.4
1.1
1.5
1.5
1.1
1.5
1.6
1.0
1.3
1.4
1.1
i.5
19-6
35.9
18.6
19-6
34.6
15.4
17-1
34-3
18.1
19.0
33-1
17.8
19.0
36.0
18.2
18.9
35-0
16.7
17.5
35,6
18.3
19.1
35-7
17.1
12,610
9,016
11,960
12,570
8,610
11,620
12,820
9,430
12,210
12,780
9,720
12,370
13,100
9,160
12,250
12,720
9,110
12,200
12,820
9,160
12,120
12,670
8,970
12,090
— _ -
2,130
_ _
_ _
_
_ _
-
_ _ _
_ _
_ _ _
_ _
• _ _
2,150
_
_ _
2, IOC
_
_ _ _
_
_ - -
_
2,200
-
_
_
_
_
_
_
_
-
_
_
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
ui
OJ
IV)
Mine
Coal Date
field of
or analy-
County town Name sis
Sheridan Carneyvllle Carney No. 2
" n n
i it ti
" Dietz Dietz No. 1
" n
n
" Dietz No. 4
"
"
"
"
ii n
" " Dietz No. 7
n it
" "
" " Dietz No. 5
"
" Kendrick Wyoming
anokeless
it n it
"
" " Sweat ' s
Proximate
analysis , ?
g
Seam
Carney
"
"
Dietz
No. 1
ti
tt
No. 2
II
II
11
tt
It
No. 3
11
tt
No. 2
II
II
Kendrick
tt
"
Arvada
"
0
-p
CQ
vH
£
_
24.7
-
24.7
-
-
22.9
-
-
22.5
-
-
24.4
-
-
22.4
-
30.3
-
—
18.3
-
D
rH
Volatl
41.9
30.8
40.9
43.1
37.6
49.9
53.2
32.5
42.2
47.0
33.3
43.0
47.0
31.1
41.2
43.9
31.9
41.0
44.7
30.8
44.2
49.1
34.6
42.2
1
o
£
58.1
40.6
53.9
56.9
33.0
43.8
46.8
36.8
47.6
53-0
37.5
48.3
53-0
39.7
52.5
56.1
30.3
50.8
55-3
31.9
45.8
50.9
40.7
49.8
.c
Wyoming
_
3.9
5.2
4.7
6.3
_
7-8
10.2
-
6.7
8.7
-
4.8
6.3
_
6.4
8.2
7.0
10.0
-
6.4
7.8
Sulfur
Ultimate
analysis , %
c
1 I
g
-H
X
o
Btu softening Free
as Btu tenpera- swelling
received dry ture,P° index
Hardgrove
grindability
index
(continued)
.4
.4
.5
.5
.4
• 5
.6
1.1
1.4
1.6
1.0
1.3
1.4
.5
.6
.7
1.2
1.5
1.6
1.3
1.8
2.0
1.2
1.4
4.9 75.3
6.3 53-2
4.7 70.7
4.9 74.5
6.2 51.5
4.7 68.4
5.0 73-0
6.1 50.6
4.6 65.6
5.2 73.1
6.3 52.3
4.9 67.5
5-4 74.0
6.3 52.6
4.8 69.5
5-1 74.2
6.3 52.3
4.9 67.3
5.4 73-3
6.4 44.8
4.3 64.2
4.8 71.4
5.7 53.9
4.4 66.0
1.5
1.1
1.4
1.5
1.1
1.4
1.5
1.3
1.6
1.8
1.2
1.6
1.7
1.1
1.4
1.5
1.2
1.5
1.7
.9
1.3
1-5
l.i
1.3
17.9
35.1
17-5
18.6
36.1
18.7
19.9
33.1
16.6
18.3
32.5
16.0
17.5
34.7
17.4
18.5
32.6
16.6
18.0
39.6
18.4
20.3
31.7
19.1
12,630 -
9,180 -
12,190 -
12,850 -
8,900 - - -
11,820 -
12,610 -
9,000 11,673
11,670 - - -
12,990 -
9,180 -
11,850 - - -
12,970 - - -
9,000 -
11,890 -
12,690 -
9,250 -
11,910 -
12,970 -
7,770 - - -
11,050 - - -
12,280 -
9,210 -
11,270 -
-
_
_
_
-
_
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
OJ
OJ
Proximate
Mine
Coal Date £
field of 5
or analy- ™
County town Nare sis Sean, g
analysis
|
« a
rj 0
«H
O *H
> fe
, ?
X
Kycmlng
Sheridan Kendrick Sweat's Arvada
" Kbol Kool Monarch 23.5
" n
n n
" "
it n
ti n
n n
n n
n n
Monarch . Monarch
. ti it
"
"
"
_
_
23.1
_
-
23.7
-
22.3
-
23.1
-
"
" " 23.1
" " _
ti n
" " 23.3
II fl _
" " ••
11 " 23.1
n n tl _
n ii n ^
" . " " " 23.2
ii ii ii n _
16.0 51.0
31.2 10.1
10.8 52.8
13.6 56.1
33-9 38.0
11.2 19.7
17.1 52.0
32.6 38.8
12.7 50.9
15.6 51.1
35.0 39.0
15.0 50.2
17.3 52.7
31.9 11.8
11.1 51.1
13-3 56.7
33.6 39.1
13.8 51.5
16.0 51.0
33.9 38.9
11.2 50.7
16.5 53.5
31.6 38.7
15.0 50.3
17.2 52.8
33-3 39.7
13.3 5K8
_
1.9
6.1
_
1.7
6.1
-
1.9
6.1
-
3.7
1.8
-
3-2
1.2
-
3.6
1.7
3.9
5.1
_
3.6
1.7
-
3.8
1.9
<§
3
UltL-rate
analysis
i
3? 8
, *
g.
e
2
&
°
Btu
as Btu
received dry
Ash
softening
tempera-
ture,F°
Free Hardgrove
swelling grlndabillty
Index Index
(continued)
1.5
.5
-7
.7
.6
.8
.9
.7
.9
.9
.1
.5
.5
.1
.5
.5
.1
.5
-5
-5
.7
.7
.1
.6
.6
.1
.6
1.8 71.6
6.6 52.0
5.2 68.0
5.5 72.6
6.3 53.1
1.8 69.3
5.2 73.8
6.5 53-9
5.0 70.7
5.3 75.5
6.3 55.3
1.9 71.1
5.1 71.7
6.1 51.7
5.0 71.0
5.3 71.1
6.1 51.1
5.0 71.0
5-2 71.5
6.5 51.8
5.0 71.5
5.3 75.3
6.5 55-1
5.1 71.7
5.3 76.2
6.1 51.6
5.0 71.1
1.1
1.0
1.3
1.3
1.3
1.6
1.7
1.1
1.1
1.5
1.1
1.1
1.5
1.1
1.1
1.5
1.0
•"••3
1.1
1.2
1.5
1.6
1.1
1.5
1.6
1.0
1.3
20.7
35.0
18.1
19.9
31.0
17.1
18.1
32.9
15.6
16.8
33.2
17."3
18.2
31.2
17.9
18.6
31.2
17.5
18.1
33.1
16.2
17.1
33.3
16.1
17.3
33.8
17.1
12,220
9,120
11,920
12,710
9,210
12,010
12,800
9,180
12,020
12,810
9,620
12,370
12,990
9,180
12,330
12,870
9,390
12,260
12,810
9,190
12,380
13,010
9,550
12,120
13,030
9,120
12,?60
_
_
_
_
_
_
_
_
_
_
2,130
_
2,200
_
_
2,270
_
_
_
_
_
1,960
-
-
-
-
__ _
_ _
_ _
_ _
_
_ _
_
_ _
_ _
_
_
_
_
_
_
_
_ _
_
_ _
_
_
_ _
_ _
-
-
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
L-G
Coal
field
or
County town
Sheridan Monarch
" Uest of
Monarch
11 11
n
n
n n
II It
II It
" "
" "
" New AcrtB
It IT
" "
" Sheridan
" "
n n
n n
II Tl
n u
Tl II
Tl It
Tl II
It tl
II 1.
Mine
Date
of
analy-
Name sis
Monarch
New Monarch
"
It
tt
n
11
Masters
it
n
New Acme
11
ir
Smith
tr
ti
Black Diamond
"
Tt
Hotchkiss No. 2
H
11
II
n
Proximate
analysis , *
I
•H
Seam £
Monarch
23-9
It __
n _
" 23.2
" -
n _
Upper 22.7
Masters
n
n
Msnarch 23.3
11 _
I! ___
Snith 23.9
H
n _
Monarch 23-0
" -
it
" 20.8
it __
n _
" 22.2
« _
m
Volati
45-5
34.3
45.1
47.2
33-0
43.0
45.3
34.8
45.0
48.7
32.1
41.8
42.7
35.8
47.0
51.1
35-1
45.6
48.6
32.8
41.4
43.8
32.2
42.7
1
o
1
a
54.5
38.4
50.5
52.8
39.9
53.0
54.7
36.6
47-3
51.3
41.3
53.9
56.3
34.2
45.0
48.9
37.1
48.2
51.4
42.1
53.1
56.2
40.3
51.7
c
Vfyoming
_
3.4
4.4
-
3-9
5.0
5.9
7.7
-
3-3
4.3
6.1
8.0
_
4.8
6.2
_
4.3
4.5
-
4.3
5.6
Sulfur
Ultimate
analysis, ?
s
60 C
"9 tj
c
z
§
S)
1
Btu
as Btu
received dry
Ash
softening Free Hardgrove
tempera- swelling grindability
ture,F° index index
(continued)
.6
.4
.5
.5
.5
.6
.6
.3
.4
.4
.5
.7
.7
.8
1.1
1.2
.4
.5
.5
.7
.8
.9
.5
.6
5-3 74.7
6.3 54.1
4.8 71.0
5.0 74.3
6.3 54.3
4.8 70.8
5.1 74.5
6.1 52.5
4.7 68.0
5-1 73.6
6.4 55-0
4.9 71.7
5.1 74.9
6.5 51.0
5.0 67.0
5.5 72.8
6.1 53.0
4.7 68.8
5-0 73.4
6.3 52.3
5.0 72.4
5.3 76.8
6.9 53.9
5.6 59.3
1-3
1.1
1.5
1.6
1.1
1.4
1-5
1.0
1.3
1.4
1.0
1.3
1.4
1.1
1.4
1.5
1.1
1.4
1.5
1.0
1.3
1.4
1.0
1.2
18.1
34.7
17.8
18.6
33-9
17.4
18.3
34.2
17.9
19.5
33. B
17.1
17.9
34.5
17.5
19.0
34.6
18.4
19.6
30.4
15.0
15.8
33-4
17-7
12,890
9,340
12,260
12,830
9,390
12,240
12,890
9,210
11,910
12,900
9,530
12,430
12,990
8,820
11,600
12,600
9,160
11,900
12,680
9,820
12,400
13,120
9,610
12,350
2,190
-
— - -.
_ _ _
— — —
— — —
_ _ _
— — _
— — —
— — —
- — —
_ _ _
_ _ _
— _ _
— — _
— _ -
— — —
_ _ _
2,090
- — -
_ _ _
2,120
_
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
VJl
(JO
County
Coal
field
or
town
Mine
Proximate
analysis , *
Date
of
analy-
Name sis seam
Moisture
Volatile
1
1
£
,C
10
Wyoming
Sheridan
Sweet-
water
n
n
n
ii
n
n
tt
n
n
n
n
rt
tt
n
tt
11
n
n
tt
tt
it
Sheridan
Black
Buttes
n
n
n
n
n
tt
tf
n
ft
tt
n
It
tt
it
tt
Gunn
Hotchklss No.
Rock Springs
Gibraltar
11
n
it
n
tt
n
tt
it
it
n
tt
tt
tt
ti
n
n
Rock Springs
Sioux City
H
ft
Gunn-Quealy B
m
2 Jfonarch
Unnamed
"
n
n
n
n
tt
ti
n
tt
tt
ft
n
n
n
it
tt
tt
ft
tt
ti
Upper
Vandyke
_
18.9
-
-
20.8
-
. -
18.9
-
-
17.2
-
-
18.7
-
-
19.5
-
_
16.7
-
-
15.9
45.2
29.2
36.0
37.9
38.4
35.8
37.6
28.9
35.7
37.6
30.3
36.6
38.6
29.2
36.0
27.7
28.2
35.1
27.1
29.2
35.0
37.0
33.2
54.8
47.8
58.9
62.1
47.1
59.2
62.4
48.1
59.2
62.4
'48.3
58.3
61.4
40.4
59.4
62.3
47.9
59.4
62.9
49.5
59-4
63.0
47.2
_
4.1
5.1
-
3.7
4.7
—
4.1
5.1
-
4.2
5.1
-
3-7
4.6
_
4.4
5-5
_
4.6
5.6
3-7
3
Ultimate
analysis , t
I
1
•z.
1
Ash
Btu softening Free
as Btu tenpera- swelling
received dry ture,F° .Index
Hardgrove
grlndability
Index
(continued)
.6
.5'
.6
.6
.4
.5
.5
.4
.5
.6
.4
,.4
' .4
.4
.5
.6
.4
.5
.5
.3
.3
.4
1.1
6.0
5.6
4.4
5.6
6.0
4.6
4.9
5.8
4.6
4.8
5.4
4.2
4.4
5.8
4.6
4.8
5.9
4.6
4.9
5.5
4.3
4.6
6.0
73.4
59.0
72.7
76.5
57.1
72.1
75.6
59.2
73-0
76.9
56.2
67.9
71.6
58.5
71.9
75.3
57.3
71.3
75.4
59.7
71.6
75.8
61.8
1.3
1.5
1.8
1.9
1.1
1.3
1.4
1.4
1.8
1.9
1.5
1.8
1.9
1.4
1.6
1.9
1.4
1.7
1.8
1.1
1-3
l.l
1.3
18.7
29.3
15.4
16.4
31.7
16.8
17.6
29.1
15.0
15.8
33.3
20.6
21.7
30.2
16.7
17.5
39.6
16.4
17.4
28.8
16.9
17.8
26.1
13,080 -
10,280 -
12,670 -
13,350 -
9,910 -
12,510 - -
13,130 -
10,090 -
12,41)0 -
13,110 -
9,390 -
11,340 -
11,950 -
10,050 -
12,360 -
12,950 -
9,840 -
12,230 -
12,930 -
10,330 -
12,390 -
13,120 -
11,880 -
_
_
_
_
_
_
_
_
_
_
_
_
_
_
_
-
-
_
-
-
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
v_n
LJO
cr\
Coal
field
or
County town
Mine
Proximate
analysis , *
c
Date |
of 5
analy- ™
Name sis Seam £
Volatile
I
1
•H
PC,
1
Doming
Sweetwater Gunn
n
n
if
"
n
"
"
M ti
I? tl
II fl
II ft
tt 11
n tt
n n
n n
n n
n ft
ti ti
w tt
n 11
it ti
1! If
Gum-Quealy B
11
n
n
n
n
n
n
it
ft
it
it
11
"
it
n
IT
It
II
n
Gunn-Quealy A
11
If
Upper
Vandyke
n _
15.7
n _
n _
13-4
tt _
ti
23.3
ti _
ti _
13.7
11 _
ti _
Lower 17.6
Vandyke
n _
« _
No. 11 16.3
« _
n _
Upper 13.5
Vandyke
"
"
39.5
41.4
33.5
39.7
40.9
34.9
40.3
41.4
31.9
41.6
43.5
34.8
40.3
41.0
31.1
37.7
39.6
34.9
41.7
42.7
35.0
40.5
42.1
56.1
58.6
48.4
57.5
59.1
49.5
57.1
58.6
41.5
54.1
56.5
50.1
58.0
59.0
47.5
57.7
60.4
46.7
55.8
57.3
48.1
55.7
57.9
4.4
-
2.4
2.8
-
2.2
2.6
-
3-3
4.3
1.4
1-7
-
3.8
4.5
-
2.1
2.5
-
3-3
3.8
-
Sulfur
Ultimate
analysis , f
Hydrogen
i
Nitrogen
X
o
Ash
Btu softening free Hardgrove
as Btu tenpera- swelling wirdabllitv
received dry ture.F0 index index
(continued)
1.3
1.4
.9
1.1
1.1
1.0
1.1
1.1
.5
.7
.7
1.0
1.1
1.2
1.1
1.4
1.4
-9
1.0
1.1
1.0
1.2
1.2
5.0
5.3
5.1
5.?
5.3
5.8
4.9
5.1
5.5
3.8
4.0
6.1
5-3
5-3
6.2
5-2
5.H
6.2
5-2
5-3
5-9
5.1
5.3
73-4
76-9
63.1
74.9
77-1
64.3
74.3
76.3
50.2
65.4
68.3
64.5
71.7
76.0
60.4
73.3
76.8
63.6
76.0
77.9
64.1
74.2
77.1
1.5
1.6
1.3
1-5
1.6
1.2
1.4
1.4
1.0
1.4
1.4
1.2
1.4
1.4
1.3
1.6
1-7
1.3
1.6
1.6
1.3
1.5
1.5
14.4
14.8
26.2
14.5
14.9
12.5
15.7
16.1
39.5
24.4
25.6
25.8
15.8
16.1
27.2
13-9
14.7
25-9
13-7
14.1
24.4
14.2
28.1
12,940 -
13,540 -
11,140 _ _ _
13,220 -
13,610 -
11,460 -
13,230 -
13,590 - - -
8,100 -
10,560 -
11,030 -
11,860 -
13,740 -
13,970 -
10,770 -
13,070 -
13,700 -
11,150 -
13,330 -
13,660 -
11,510 -
13,320 -
13,850 -
_
_
_
_
_
_
_
„
_
_
_
_
_
_
_
_
_
_
-
_
_
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
ui
oo
County
Sweet
Water
n
it
n
n
n
n
it
n
ti
n
n
n
tt
tt
n
ti
n
it
11
it
n
tt
tt
it
Coal
field
or
town
Point of
Rocks
n
n
n
n
n
n
ti
it
it
n
n
n
n
n
n
ti
n
it
»
n
Rock
Springs
it
n
it
Mine
Date
of
analy-
Name sis
Point of Rocks
n
n
n
n
n
n
tt
n
n
n
n
n
ti
"
it
n
tt
ti
M
ii
Ifriion Pacific
No. 1
tt
n
Rock Springs
No. M
Proximate
analysis, *
I
Seam
Lower
n
n
Upper
n
n
Tt
tl
tt
tl
ft
n
tt
n
n
it
n
tt
tl
II
IT
No. 1
it
11
t»
ei o 3
S t-i o
Z3 *H
41 +3 TJ
" 5 %
£ £ fi
16.6 30.2 14.0
- 36.3 52.7
- 10.8 59.2
16.0 33.2 46.1
- 39-5 55.3
- 41.7 58.3
14.3 33.2 47.1
- 38.8 54.6
- 41.4 58.6
14.0 31.1 50.8
- 36.2 59.0
- 38.0 62.0
16.9 28.4 51.3
- 34.1 61.8
- 35.6 64.4
17.9 29.5 49.3
- 36.0 60.0
- 37.4 62.6
18.8 29.5 48.2
- 36.3 59.4
- 37.9 62.1
8.5 35.6 50.4
- 38.9 55.1
- 41.4 58.6
11.4 36.2 46.5
1
Vfyomlng
9.2
11.0
_
4.4
5.2
5?4
6.6
-
4.1
4.8
_
3.4
4.1
-
3-3
4.0
-
3-5
4.3
5.5
6.0
_
5.9
1
iH
£
Ultimate
analysis, %
g
2 ^
3! i
g
£?
.p
*H
z
1
I
Btu
as Btu
received dry
Ash
softening Free Hardgrove
tempera- swelling grindability
ture.F0 index Index
(continued)
-7
.8
.9
.8
.9
1.0
.7
.9
.9
.6
.7
.7
.6
.7
.7
.5
.6
.6
.6
.7
.7
.8
.9
.9
.8
5.3 55.6
4.1 66.7
4.6 75.0
5.0 59.4
3-9 70.7
4.1 74.6
4.7 54.6
3.6 63.2
3.9 67.5
5.4 60.3
4.5 70.1
4.7 73.6
5.8 60.6
4.7 73.0
4.9 76.1
5.9 59.5
4.7 72.4
4.9 75.4
5.9 59.0
4.7 72.7
4.9 76.0
5.4 66.2
4.8 72.3
5-1 76.9
5.6 63.9
1.1
1.3
1.5
1.2
1.4
1.5
1.4
1.6
1.7
1.3
1-5
1.5
1.2
1.5
1.6
1.2
1.5
1.6
1.2
1.5
1.6
1.2
1.3
1.4
1.4
28.1
16.1
18.0
29.2
17.9
18.8
33.6
24.4
26.0
28.3
18.4
19.5
28.4
16.0
16.7
29.6
16.8
17.5
29.8
16.1
16.8
20.9
14.7
15-7
22.4
9,410
11,290
12,690
9,550
11,730
12,280
8,330
9,720
10,380
10,180
11,830
12,420
10,410
12,530
13,070
10,220
12,450
12,970
10,010
12,460
13,030
11,830
12,940
13,760
11,210
-
— — _
- _ —
- _ -
— _ _
- — _
- _ _
_ _
- -
— _ _
— _ —
_ _ _
_
_
_ _
_
_
_
_ -
_
_
_
_
_
— ~ _
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
V7I
00
oo
County
Sweet-
Water
it
n
n
11
It
it
n
it
it
it
"
11
it
it
it
it
it
11
it
n
11
Coal
field
or
town
Rock
Springs
n
IT
tr
ti
n
ri
11
TI
11
II
11
II
II
"
11
It
It
II
It
"
n
Mine
Date
of
analy-
Naroe sis Seam
Rock Springs No. 1
No. 4
n n
Sweetwater No. 2 No. 7
n n
it n
Union Pacific No. 5
013 No. 5
11 it
it it
Blairtown No. 3
n it
n it
Union Pacific No. 7
No. 3
it n
n tt
Union Pacific "
No. 10
M II
fl II
Old No. 6 No. 6
it ii
ii it
No. 5 No. 7
it n
Proximate
analysis , *
g
_O
(D 0)
b •"*
•p -p
•H i— 1
£ &
- 40.9
- 13.8
9.8 32.6
- 36.2
- 40.2
10.9 30.8
- 34.6
- 41.9
11.5 36.8
- 41.6
- 42.4
14.5 33-3
- 38-9
- (ll.i*
13.0 34.0
- 39.1
- 40.6
13.1 30.6
- 35.2
- 37.1
10.5 36.4
- 40.7
a
c
%
K
£
52.4
56.2
48.6
53.8
59.8
42.7
47.9
58.1
50.1
55.6
57.6
47.1
55.0
58.6
49.8
57.2
59.4
51-9
59-8
62.9
50.9
56.8
1
Wyoming
6.7
_
9.0
10.0
-
15.6
17-5
1.6
1.8
-
5.2
6.1
_
3.2
3.7
4.U
5.0
2.2
2.5
c!
tH
a
Ultimate
analysis, %
C
& _
60 C
•D £H
S 8
c
If
*j
g
1
S
X
o
Btu
as Btu
received dry
Ash
softening Free Hardgrove
tempera- swelling grindability
ture ,F° index index
(continued)
.9
.9
• 9
1.0
1.1
1.0
1.1
1.4
.8
.9
.9
1.0
1.2
1.2
.8
.9
.9
.H
-5
.5
.9
1.0
4.9 72.1
5-3 77.3
5.5 63.8
4.9 70.7
5.5 78.5
4.8 54.0
4.1 60.6
4.9 73.4
5.9 68.3
5.8 77.2
5.4 78.6
5.6 61.5
4.6 71.8
4.9 76.5
5.9 64.9
5.1 74.6
5-3 77.5
5.U 61.3
4.6 70.6
4.9 74.4
5.4 69.0
4.7 77.0
1.6
1.7
1.1
1.2
1.4
.9
1.0
1.2
1.2
1-3
1.3
1.1
1.3
1.4
1.2
1.4
1.4
1.4
1.6
1.6
1.3
1.5
13.8
14.8
19.7
12.2
13.5
23-7
15.7
19.1
22.2
13-5
13-8
25.6
15.0
16.0
24.0
14.3
14.9
27.0
17-7
18.6
21.2
13-3
12,650
13,560
11,300
12,530
13,920
9,990
10,540
12,770
12,220
13,800
14,070
10,960
12,800
13,630
11,530
13,250
13,750
10,560
12,150
12,800
12,270
13,700
-
— _ _
_
_
_
_ _
_ _ _
_
_ _
_ _ _
_ _ _
_ _ _
_
_ _
-
_ - -
_ _
_ _
_ _
_ _
_ _ _
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
ui
uo
County
Coal
field
or
town
Mine
ProxljTBte
analysis, ?
!
4) 111
Date £ jj
of ra ca
analy- •* IH
Name sls Seam £ !>
a
o
•H
JC
m
Wyoming
Sweet-
water
n
n
n
tt
n
n
tt
it
It
II
n
tt
tt
n
n
ii
tt
n
it
ti
Rock
Springs
n
n
tt
tt
tt
n
tt
ti
tt
n
it
it
tt
tt
H
tt
n
it
n
tt
„
it
n
No. 5
No. 4
n
tt
Prospect
n
n
n
n
n
Interstate
tt
tt
Kappes
n
tt
Kent
n
tt
Miller
M
MenKinney
No. 7 - 41.7
9.8 34.3
- 38.0
- 39.5
Unnamed 19.8 35-7
- 44.5
- 48.6
" 21.0 31-3
" - 39.7
" - 43.9
Inter- 13.4 36.3
state
" - 41.9
- 46.4
Uhnamsd 24.2 32.1
" - 42.4
" - 44.6
" 13.1 35.6
" - 40.9
- 43.8
12.8 34.8
1 - 39.9
1 - 41.1
8.1 38.8
- 42.2
58.3
52.5
58.2
60.5
37.8
47.1
51.4
40.1
50.7
56.1
41.8
48.3
53-6
40.0
52.7
55.4
45.6
52.5
56.2
49.9
57.2
58.9
42.5
46.2
-
3.4
3-8
6.7
8.4
_
7-6
9.6
8.5
9.8
3-7
4.9
5-7
6.6
_
2.5
2.9
10.6
11.6
i-H
a
Ultimate
analysis , %
I
1
1
!
Ash
Btu softening Free
as Btu tenpera- swelling
received dry ture.F0 index
Hardgrove
grlndabillty
index
(continued)
1.0
1.0
1.1
1.2
.7
.8
.9
.8
1.0
1.1
.8
1.0
1.1
'.6
.7
.4
1.6
1.7
.8
.9
.9
1.0
4.8
5-8
5.2
5-4
5.1
3.6
4.0
5.4
3.9
4.3
5.9
5.1
5.6
5.6
3.8
4.0
5.9
5.2
5.5
5.8
5.1
5.2
5.6
5.1
79.0
68.4
75.8
78.8
48.1
60.1
65.5
49.6
62.7
69.4
59.8
69.1
76.6
49.2
64.9
68.2
62.9
72.3
77.4
64.8
74.3
76.5
61.7
67.1
1.5
1.2
1.4
1.4
1.3
1.7
1.8
1.0
1.3
1.5
1.2
1.3
1.5
1.1
1.4
1.5
1.2
1.4
1.5
1.3
1.5
1.5
1.3
1.5
13-7
20.2
12.7
13.2
38.1
25.4
27.8
35.6
21.5
23.7
23.8
13.7
15.2
30.9
24.4
25.6
22.0
12.9
13-9
24.8
15-3
15.9
19.8
13.6
14,050 -
12,260 -
13,700 -
14,050 -
12,260 -
13,580 -
14,120 - - -
8,200 -
10,380 - . -
11,490 -
10,460 -
12,080 -
13,390 -
7,890 - - -
10,410 -
10,950 - - -
11,110 -
12,790 - - -
13,690 - - -
11,360 -
13,030 -
13,410 - - -
11,130 - - -
12,100 -
-
-
-
-
_
—
—
—
—
~
—
—
-
—
—
~
~
~
~
—
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
VJl
-Cr
O
County
Coal
field
or
town
Mine
Proximate
analysis , *
!
Date g
of 3
analy- .2
Name sis Seam £
Volatile
a
o
T3
a
E
.c
to
<
Wyoming
Sweet-
water
n
11
11
n
it
n
11
If
M
«
11
11
11
11
11
«
11
If
11
II
II
II
n
11
Rock
Springs
11
n
n
Superior
ii
M
it
n
n
»
M
n
11
11
n
n
n
n
11
ii
11
11
it
ii
MsnKinney
Ityers
IT
It
Superior C
it
it
n
"
n
Siperlor D
n
"
n
n
it
Prospect
n
tt
Superior A
it
n
n
n
11
Unnamed
11 13-8
n _
n _
No. 1 13.7
It _
1? _
" 13.1
"
n _
13-8
n _
_
14.6
_
_
No. 3 18.4
-
_
No. 7 12.7
M _
It __
No. 1 10.6
n . _
n —
47-7
38.9
145-1
18.0
32.4
37.6
38-9
35.8
itl.l
42.8
31-5
36.6
38.6
31.1
4o.o
11.7
31.6
140.2
141.1
32.8
37.6
39.7
31.8
38.9
HO. 8
52-3
12.2
149.0
52.0
51.0
59.6
61.1
47.7
55-0
57.2
50.5
58.5
61.6
17.8
55.8
58.3
48.4
57-8
58.9
50.0
57.2
60.3
50.1
56.4
59-2
_
5.1
5.9
2.9
3.1
3^4
3-9
_
4.2
4.9
_
3.5
4.2
_
1.6
2.0
_
4.5
5.2
4.2
1.7
-
Sulfur
Ultimate
analysis. ?
Hydrogen
I
c
4J
s.
c
Ash
Btu softening Free Hardgrove
as Btu tenpei-a- swelling grindablllty
received dry ture,P° index index
(continued)
1.2
5-5
6.4
6.8
.7
.8
.9
1.0
1.2
1.2
1.3
1.5
1.6
1.0
1.2
1.2
.5
.6
.6
.8
-9
.9
.9
1.0
1.0
5-8
6.1
5.3
5-6
5.8
5.0
5-2
5-9
5-1
5-3
5.7
4.8
5.1
5.8
4.9
5.1
5-5
4.2
4.3
5-8
5-0
5-3
5-7
5.0
5-3
75.9
60.3
69.9
71-3
67.0
76.4
79-0
66.2
76.2
79.3
63.8
74.0
77.8
63-5
71.3
77-5
57.4
70.3
71-7
65-1
74.6
78.7
67.1
75.0
78.8
1.6
1.7
2.0
2.1
1.2
1.4
l.U
1.3
1.4
1.5
1.1
1.3
1.3
1.3
1.6
1.6
1.2
1.5
1.5
1.1
1.3
1.4
1.3
1.4
1.5
15.6
21.3
10.5
11.2
23.5
13.0
13.5
22.2
12.2
12.7
23-9
13.5
14.2
24.9
13.8
14.6
33-8
21.4
21.9
22.7
13.0
13.7
20.8
12.9
13-1
13,690 -
11,110 - 2,050
12,920 -
13,710 -
11,460 -
13,390 -
13,860 -
11,620 -
12,370 -
13,920 -
11,430 -
13,250 -
13,930 -
11,380 -
13,330 -
13,910 -
9,670 -
11,850 -
12,090 -
11,720 -
13,430 -
14,160 -
12,160 -
13,600 -
14,240 -
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
—
-
-
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
-tr
H
Mine
County
Sweet-
water
n
n
n
n
n
H
tt
it
ti
it
n
n
tt
it
tt
n
n
Uinta
tl
n
ti
ti
Coal
field
or
town
Superior
n
n
IT
it
ii
n
n
n
it
it
tt
tt
it
it
it
tt
n
AlJijy
ii
"
"
"
Name
Superior
n
n
ti
n
n
Prospect
"
tt
"
n
H
n
it
it
11
n
tt
No. 5
tt
II
Michigan
looming
tt
Date
of
analy-
sis seam
B No. 7
It
tt
n
it
n
Unnamed
"
n
tt
tt
tt
it
tt
ti
it
tt
tt
Alujy
n
n
it
it
q rH
m §
1 1
10.2 31.1
- 38.0
- 40.0
11.8 37.0
- 41.9
- 13.6
13.8 31.7
- 36.8
- 39.1
13.6 31.7
- 36.6
- 39.1
13.0 32.8
- 37-7
- 38.9
22.1 31.3
- 10.3
- 12.8
11.1 36.8
- 43.0
- 17.0
11.1 35.3
- 11.2
Proximate
analysis. ?
§
fl
a
o
TS
X
E
51.1
56.9
60.0
17.8
51.3
56.1
49.5
57.4
60.9
18.8
56.5
60.6
51.6
.59.3
61.1
11.9
53-7
57.2
11.6
18.6
53.0
31.1
40.0
1
Vfyoming
4.6
5.1
-
3.4
3.8
5.0
5-8
_
5.9
6.9
2~6
3-0
-
4.7
6.0
-
7.2
8.4
-
16.2
18.8
i§
1
Ultimate
analysis, %
g
8 ^
£ 1
g
g
i
n
5
Btu
as Btu
received dry
Ash
softening Free Hardgrove
tenfjera- swelling grindabllity
ture,F° index index
(continued)
1.2
1.3
1.4
1.0
1.1
1.2
.9
1.0
l.l
.8
.9
1.0
.7
.8
.9
.8
1.0
1.1
.2
.3
.3
4.5
5.2
5.8 66.9
5.2 74.5
5.4 68.5
5.9 67.9
5.2 76.9
5.4 80.0
5.8 61.9
4.9 71.8
5.2 76.2
5.5 61.3
4.6 71.0
4.9 76.2
5.3 64.5
4.1 71.2
4.5 76.5
5.6 52.4
4.0 67.3
4.2 71.6
5.4 60.0
4.4 70.1
4.8 76.5
5.3 18.9
1.3 f/, .0
1.5
1.7
1.8
1.1
1.6
1.7
1.1
1.3
1.1
1.3
1.5
1.7
1.2
1.1
1.1
.9
1.2
1.3
1.2
1.3
1.5
.8
1.0
20.0
12.2
12.9
20.4
11.4
11.7
25.3
15.2
16.1
25.2
15.1
16.2
25.7
16.2
16.7
35.6
20.5
21.8
26.0
15.5
16.9
24.3
13.7
12,030
13,400
11,110
12,000
13,600
11,110
10,790
12,520
13,390
10,530
12,190
13,090
11,330
13,020
13,420
8,760
11,250
11,970
10,150
12,210
13,330
8,820
10,270
— — _
- _
- - _
_ _
_ _
_ _
_ _
_ _
_ _
_ _
_ _
_ -
_ _
_ _
_ _
- . - -
_ -
- -
_ -
_
_ -
_
- -
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
ro
County
Ulnta
"
It
11
II
Washakle
tl
11
Weston
11
11
II
11
It
11
It
11
it
"
n
Coal
field
or
town
Alrrp
Evanston
Spring -
Valley
"
n
Tensleep
n
it
Cambria
n
n
it
n
n
Upton
tt
»
rr
it
PI
Mine
Date
of
analy-
Mane sis
Michigan
Wyoming
Cummnty
"
Richardson
ti
n
Unoperated
n
it
Antelope No. 3
n
it
Antelope No. it
n
tl
Krogman
n
it
Prospect
it
tr
Proximate
analysis , 1
I
g
I
•H
Seam £
Kimy
Unnamed 17.6
tt
tl _
Spring- 6.9
Valley
n
Tl _
Unnaned 16.3
it _
"
" 10.0
n _
" -
10.8
« _
11 _
31^9
It
II __
26.1
ir _
n _
to S
t-t O
^H
•P "3
1 a
50.7 49.3
33-4 13-2
40.6 52.4
13.7 56.3
35.6 H3.8
38.2 47.1
44.8 '55,2
35.8 32.6
42.8 39.0
52-3 47.7
39-1 34.3
40.5 38.1
53-3 46.7
39.1 35.1
40.5 38.1
53.7 47.3
26.5 34.5
38.9 50.7
43.4 56.6
31.1 36.8
42.0 49-9
45.7 54.3
.c
If!
<
Vfyoming
_
5-8
7.0
13.7
14.7
15.3
18.2
-
16.6
18.4
_
15.0
18.4
_
7.1
10.lt
-
6.0
3.1
-
r§
rH
3
U5
Ultimate
analysis f %
c
s
&
P
•6
>>
g
1
C
g1
41
2
i
So
>i
x
0
Btu
as Btu
received dry
Ash
softening ?ree Hardgrove
tenpera- swelling grindabillty
ture,F° index index
(continued)
6.4
-7
.9
.9
.9
1.0
1.2
1.0
1.2
1.5
4.9
5-4
6.7
4.9
5.4
6.6
.5
.8
.9
.6
.8
.fi
5.4
6.0
4.9
5.3
5.0
4.5
5.3
5.6
4.6
5.6
5.4
4.7
5.8
5-5
4.7
5.7
6.4
4.3
4.7
6.3
4.6
5.0
70.1
59-3
72.0
77-5
63-7
63.4
80.2
50.8
60.7
74.3
55.2
61.3
75.2
56.1
61.3
75.6
W.2
67.8
75.7
49.4
56.8
7P.7
1.2
1.1
1.3
1.4
1.1
1.2
1.4
.7
-9
1.0
.7
.8
.9
.7
.8
1.0
.9
1.2
1.4
.9
1.2
1.^
16.9
27.1
13-9
14.9
15.6
10.2
11.9
26.6
14.4
17.7
17.2
9-4
11.4
17.8
9-4
11.1
39-0
15.5
17-3
36.8
18.5
?0.2
12,640
10,290
12,490
13,430
11,350
12,180
14,280
8,860
10,580
12,940
10,240
11,390
13,950
10,340
11,390
13,940
7,640
11,220
12,520
8,370
11,320
1?,320
2,240
— _
-
-
_ _ _
_
_ - —
-
— — —
— — —
— — —
— —
— — —
2,230
— — —
— — «•
2,400
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
County
Sheridan
it
Lincoln
Sheridan
VJ1 "
Jr «
UJ "
Sweet-
water
n
Lincoln
n
n
n
n
n
tt
«
Coal
field
or
town
Sheridan
n
Kenmsrer
Sheridan
n
n
tt
Reliance
11
Adavllle
Lower
Mine
Date
of
analy-
Name sis
Big Horn
ti
Elkol
Big Horn
H
n
tt
Reliance Auger
Reliance Strip
Elkol
Coredrlll
Willow Creek
Spring Lees
Valley
Willow
Creek
ti
„
n
n
Coredrill
n
n
n
Goner
Proximate
analysis, 1
I
£
-H
Seam •£.
Monarch 20.9
" 21.9
" 21.2
" 21.7
" 23.0
" 21.1
" 21.8
Rock 16.0
Spring No. 3
Rock 15-5
Spring No.ll
19. 1
2.5
1.1
3-2
3.1
3.1
2.8
2.7
0)
Volatil
13.1
141.9
12.3
11.7
12.6
13.7
12.3
16.1
15.0
31.5
11.1
36.7
36.3
36.1
38.5
37.1
38.2
a
o
1
£
19.2
51.5
51.2
52.3
51.7
19.9
51.5
19.2
17.1
12.6
50.6
18.2
51.1
19.7
51.1
51.7
53.7
•g
-a:
Wyoming
7.1
6.6
3-5
6.0
5.7
6.1
6.2
1.1
7.9
3.5
5.8
11.0
9.1
10.8
7.3
8.1
5.1
Sulfur
Ultimate
analysis , %
c
u c
£ 0
c
4J
3
1
Btu
as
received
Btu
dry
Ash
softening Free
tenpera- swelling
ture,F° index
Hardgrove
grlndabillty
Index
(continued)
.9
-7
.8
'.6
.8
.6
1.0
1.0
.9
1.1
.1
.7
1.1
1.1
.8
1.0
-
-
-
-
5-1 72.9
5.0 71.1
6.3 58.2
5.6 71.1
1.7 68.6
5.2 71.8
5.2 69.5
5.5 72.9
5.1 72.7
5.5 75.1
-
-
-
~
1.6
1.6
1.1
1.3
1.2
1.1
1.1
1.3
1.2
1.3
-
-
-
-
15.0
13.1
30.0
11.5
11.1
12.1
12.3
11.9
11.8
11.1
9,800
9,570
10,010
9,590
9,500
9,510
9,510
10,700
10,600
10,570
11,350
13,910
11,120
11,030
11,120
11,200
11,370
12,330
12,250
12,720
12,250
12,350
12,200
12,200
12,710
12,550
-
-
-
_
-
-
-
2,120
2,100
— ~
2,170
2,170
2,070
2,070
2,290
2,210
— -
-
-
-
-
—
—
_
*~
-
-
-
-
-
-
-
-
~
~
~
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
ui
-c-
-t
County
Coal
field
or
town
Mine
Proximate
analysis , ?
§
Date g
Of 41
analy- ™
Name sis Seam s
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
ui
-Cr
VJ1
County
Carbon
n
n
Hot
Springs
n
n
n
It
Lincoln
Sheridan
"
"
"
"
Coal
field
or
town
Hanna
If
It
firass
Creek
n
n
n
n
Kenmerei*
"
"
Sheridan
"
Mine
tete £
of 1
analy- "
Name sis seam £
Rosebud 11.2
" 11.2
" 12.1
Grass Creek 12.1
" 12.3
" 12.1
" 10.9
" 12.7
EUcol 21.6
" 20.7
19.7
" 22.1
Big Horn Monarch 21.3
n n 21.1
" 21.2
" 21.0
20.5
23.9
23.9
" 22.2
" 21.2
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
Ul
-Cr
ON
County
Sweet-
water
it
"
"
Canpbell
"
Cartoon
Lincoln
Sheridan
11
n
Carbon
tt
11
Coal
field
or
town
Rock
Spring
"
"
Gillette
"
Hanna
Kemnerer
Acne
"
"
Keirmerer
n
Tt
Mine
Proximate
analysis , ^
I
Date
of
analy-
Name sis Seam
Rainbow
"
it
Wyodak
11
Nuggett
Elkol
Big Horn
"
n
t!
Hanna
"
11
Smith-
Roland
t?
Adaville
Monarch
Bottom
Bench
»
it
"
Moisture
9.1
10.2
10.1
10.1
12.1
29.9
31.0
15.0
20.9
24.0
19.2
20.6
21.9
13.0
13.4
13-9
Volatile
43.2
43.4
13-3
43.6
42.7
43-6
43-5
10.6
12.1
11.5
42.7
41.6
42.5
42.2
42.4
41-3
i
E
K
Wyoming
55.1 1.7
51.6 2.0
51.6
53.8
50.8
16.0
13.5
51.8
55-3
53.0
51.8
53.0
52.2
52.9
51.2
52.2
2.1
2.6
6.5
10.4
10.1
7.6
2-9
5-5
5.5
5.1
5-3
1.9
6.4
6.5
Ultimate
analysis . %
iiil
(continued)
.8
.8 -
.8 -
.9 - - -
1.3 5-1 73.5 1-8
-9
.9 - - -
1.1 -
.8
.7
.6
.6
.5
.8
.9
.9
Ash
g Btu softening Free
g> as Btu tempera.- swelling
0 received dry ture,P° index
12,480
- 12,380
12,400
12,350
11.8 11,520
8,010
7,960
10,370
10,110
9,390
10,080
9,750
9,700
11,140
10,870
10,810
13,850
13,780
13,790
13,740
13,100
11,470
11,540
12,210
12,800
12,360
12,490
12,280
12,430
12,810
12,550
12.56C
2,080
2,160
2,180
2,180
2,080
2,280
2,260
2,240
-
2,130
2,160
2,190
2,180
2,200
2,150
2,100
Hardgrove
grindabUlty
index
-
52
-
51
-
-
-
40
_
_
-
_
„
52
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
County
Coal
field
or
town
Mine
tete |
of 5
analy- -3
Nane sis seam £
Volatile
Proximate
analysis , ?
u
•H 10
ft. •*
Ifyoming
Carbon
Lincoln
n
VJ-) Sheridan
-t
~^ Sweet-
water
tt
Lincoln
Sheridan
n
Lincoln
Sheridan
n
Carbon
Lincoln
Kennerer
if
n
Sheridan
n
Rock
Springs
n
Kenraerer
Sheridan
n
Kemmerer
Sheridan
it
Hanna
Kenroerer
Hanna
EUrol
Sorensen
Big Horn
n
Rainbow
n
Elkol
Big Horn
n
ELkol
Big Horn
n
Rosebud
Elkol
11.6
Adavllle 20.2
28.6
Monarch 21. 6
22.6
9.9
10.0
Adaville 20.1
Monarch 20.5
" 22.3
Adavllle 20.0
Monarch 21.7
22.2
Uncor- 11.3
related
Adavllle 20.2
51.2
12.7
13.9
13.5
12.1
12.9
12.8
53-1
11.7
12.8
13.0
11.9
13.0
11.7
12.3
52.2
51.5
50.8
51.1
52.2
55.3
55.2
53.8
19.6
51.6
53.8
19.1
51.8
50.1
53-1
6.6
2.8
5-3
5.1.
5.1
1.8
2.0
3-1
5.7
5.6
3.2
5.7
5.2
7.8
1.3
Ultlnete
analysis , %
a & i i
(continued)
1.0
.7 - - -
• 3
.6
.5
.8 5.1 78.2 1.8
.7 - - -
.7 - - -
.7
.5 -
.7
.6 -
• 5 - - -
.9 - - -
.9 - - -
I Btu
g> as Btu
o received dry
10,650
10,310
8,020
9,850
9,590
12.0 12,110
12,120
10,250
10,050
9,630
10,250
- • 9,850
9,590
10,900
10,070
12,170
12,920
11,230
12,560
12,390
13,810
13,800
12,880
12,610
12,390
12,810
12,580
12,330
12,200
12,620
Ash
softening Free
tenpera- swelling
ture,F° index
2,100
2,230
2,170
2,210
2,250
2,270
-
2,190
2,210
2,180
2,220
2,180
_ _
Hardgrove
grindability
Index
_
81
-
-
_
-
-
-
_
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
VJ1
-Cr
oo
Mine
County
Coal
field
or
town
Hame
Date
of
analy-
sis Seam
Moisture
Proximate
analysis , ?
Volatile
o
!
I
Wyoming
Carbon
n
"
11
ii
n
M
11
II
tl
If
It
Tt
rl
tl
It
tt
n
"
11
n
it
"
"
n
Hanna
M
H
11
fl
11
tt
tt
It
tt
If
It
tt
M
M
tl
II
II
It
It
It
II
II
"
II
Sary
n
n
tl
n
It
it
II
It
It
it
"
tt
ii
n
Nugget
it
"
n
n
n
rt
"
"
ii
1950 Lower
Bench
Finch
1949 "
1950
1950 "
1949 "
1949
1948 "
1950
1949 "
1950 "
1950
1950 "
1948
1950 "
1950
1949
1950
1950
1949
1948
1949
1948
1949
1948
6.0
9-5
7.7
8.6
7.6
7.5
8.6
7.0
9.0
7-9
9-7
12.4
7-5
9-7
9.9
13.7
6.9
11.4
11.4
11.5
10.4
10.0
10.3
14.0
10. ^
42.6
43.6
43.6
45.8
44.6
46.4
44.5
46.1
44.8
42.9
43.8
45.9
42.9
44.2
41.9
44.1
42.8
46.3
45-7
43.8
45-7
46.5
45-9
45.6
41.6
48.6
49.7
49.7
45.1
47.6
45.5
45.4
43.8
47.3
49.4
47.6
47.5
44.3
46.4
46.5
48.7
49.8
47.4
48.9
50.1
48.5
47.1
47.2
48.8
50.6
8.8
6.7
7.5
9.1
7.8
8.1
10.1
10.1
7-9
7-7
8.5
6.6
12.3
9-4
11.6
7.2
7.4
6.3
5-4
6.1
5.8
6.4
6.9
5.6
7-8
Ultimate
analysis, %
o> £* o z
(continued)
.7 - - -
-7
.5 - - -
.7
.6 - - -
.6
.6
.7
.6 - - -
.6
.8 - - -
1.0
.8 - - -
.7 - - -
1.1 -
.5 - - -
.4
.4 - - -
.4 - - -
.4
.3 - - -
.5 - - -
.4
.5 - - -
.5 - - -
1 Btu
& as
o received
11,720
11,500
11,630
11,440
11 730
11,740
11,260
11,530
11,460
11,600
11,160
11,280
11,040
11,100
10,890
10,880
11,380
11,300
11,390
11,220
11,520
11,330
11,410
11,030
11 ,140
Ash
softening Free
Btu tenpera- swelling
dry ture.F0 index
12,470
12,710
12,600
12,520
12,700
12,680
-12,320
12,400
12,600
12,600
12,360
12,880
11,940
12,290
12,090
12,600
12,220
12.7SO
12,850
12,670
12,860
12,580
12,720
12,820
12,46C
_ _
_ _
_ _
_ _
_ _
_
2,280
2,280
2,210
2,260
2,270
2,280
2,240
2,240
2,100
_
_
-
_
-
-
-
-
2,250
Hardgrove
erindabilitv
index
„
—
_
„
_
„
_
_
„
_
_
_
_
_
_
_
_
_
-
_
-
-
-
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
VJI
-Cr
vo
County
Carbon
n
n
n
n
it
it
it
Ifot
Springs
n
n
n
n
n
Lincoln
n
n
11
it
Sheridan
Coal
field
or
town
Harma
»
Gebo
tt
n
n
n
tt
Brilliant
»
n
tt
EUtol
Kleenbum
Mine
Name
Nuggett
n
n
tt
n
it
Shirley
Hanna
ti
Burnell
Mines
n
tt
n
rt
ti
Brilliant
No. 8
H
M
ti
Elkol
Big Horn
No. 1
1
Date
of
analy
sis
1919
1950
1949
1950
1950
1949
1948
19t9
1948
1948
1918
1948
1948
1948
1948
1948
1948
1949
1949
1948
Seam
Nos. 3
& 5
tt
n
it
n
tt
Fron-
tier No.
»
n
ti
Adavllle
Carney
-P
3
£
12.4
11.9
12.2
10.7
13.8
13.6
12.5
10.8
15.9
16.1
14.8
10.9
15.3
14.7
4.0
1
4.5
8.2
9.2
13.5
22.?
4)
r-t
-H
V
s
§
43.5
44.4
44.4
45.5
43.7
44.3
40.2
40.3
38.9
39.5
39.3
41.2
37-3
38.3
44.5
43-9
42.5
41.8
43.4
43.4
Proxli
analys
•a
s
E
47.8
48.2
47.4
47.5
48.5
48.9
48.5
47.2
54.6
54.3
53.8
50.8
50.5
50.7
47.7
46.9
48.1
48.0
51.8
49.14
rate
Is, %
js
3.
Wyoming
8.7
7.4
8.2
7.0
7-8
6.8
11.3
12.5
6.5
6.2
6.9
8.0
12.2
11.0
7.8
9-2
9.4
10.2
4.8
7.''.
Ultimat
analysis
1 1 g
*•* ±1 P
rH *O M
A & 8
(continued)
.6
.5 - -
.5 - -
.5 - -
.5 - -
.5 - -
.8 -
.6 - -
.7 -
.6 5.0 73-4
.6 - -
.7 - -
.7 - -
-7 - -
.6 - -
.8 - -
.8 - -
.9
.6 - -
.5 - -
e
. X
g 1, Btu
£ & as
z o received
10,700
10,890
10,820
- 11,130
10,660
10,840
10,530
10,480
10,750
1.3 13. 5 10,830
-* 10,850
11,210
10,130
10,360
12,380
12,180
11,710
- 11,380
11,020
9,190
Btu
dry
12,210
12,360
12,320
12,460
12,370
12,550
12,030
11,750
12,780
12,910
12,730
12,580
11,950
12,140
12,900
12,760
12,760
12,530
12,740
11,810
Ash
softening Free
tempera- swelling
ture,F° index
_ _
2,210
2,260
2,170
- -
2,220
2,350
2,350
2,490
2,520
2,540
- -
2,380
2,420
-
-
2,230
2,190
- -
-
HardgFove
grindabillty
index
_
-
-
-
-
-
-
-
-
-
-
-
-
—
-
-
-
-
-
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
Ul
Ul
o
Mine
County
Coal
field
or
town
Name
Date
of
analy-
sis Seam
I
•P
T\
£
0)
iH
•H
I
Proximate
analysis , J
c
3
tn
.
Wyoming
Sheridan
n
IT
II
IT
II
II
II
II
II
IT
It
II
11
II
11
Sweet-
water
Kleenburn
Monarch
TT
IT
It
II
II
11
II
II
II
11
It
It
TI
Dines
"
Big Horn
No. 1
n
Monarch
ii
it
ii
n
n
it
n
n
n
it
it
it
Dines
n
1948
1948
1949
1949
1950
1950
1949
1950
1948
1948
1950
1949
1948
1949
1948
1949
1950
1948
1949
1949
1950
1948
Carney
II
It
Monarch
it
n
ii
u
u
n
ii
n
No. 15
tl
It
21.0
23.8
24.2
19.0
20.4
20.6
19.7
20.2
17.9
20.9
18.4
21.9
21.3
17.5
21.1
21.4
22.3
20.9
21.7
13-1
15.5
16.1
42.8
43.4
42.3
45.1
42.7
43.0
42.9
43.1
41.1
43.4
41.2
42.6
43-3
43.0
42.5
42.8
43.0
43.2
42.8
40.0
42.7
39-9
50.0
49.8
50.1
48.8
52.0
50.8
51.6
51.5
53.5
50.2
51.6
51.4
49.7
51.6
50.8
50.2
50.2
49.3
50.7
56.4
53.1
54.8
7.2
6.8
7.6
6.1
5.3
6.2
5.5
5.4
5.4
6.4
7.2
6.0
7.0
5.4
6.7
7 0
6.2
7-5
6.5
3.6
4.2
5.3
Ultimate
analysis, %
1 B 1
H •§ fi £
(continued)
.8
.7 - - -
• 7
.8
.8 -
.7 - - -
.7 - - -
.6
'.6 - - ~
• 7
.7
.7 - - -
.5
.6
.7
.7
.8
.8
.8
.fi-
ll Bfcu
g> as Btu
o received dry
9,390
9,200
9,160
10,020
9,830
9,570
9,880
9,820
10,070
9,650
9,830
9,350
9,600
10,100
9,510
9,530
9,560
9,560
9,540
11,280
11,000
10,800
11,890
12,070
12,090
12,370
12,350
12,050
12,310
12,300
12,260
12,200
12,050
11,970
12,200
12,240
12,050
12,130
12,180
12,080
12,180
12,970
13,020
12,870
1
soft
ten
tui
2,
2,
2,
2,;
Ash
tening
mpera- swelling
re,P° index
2,200
Hardgrove
grindatility
index
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
v_n
Mine
Coal
field
or
County town
Name
Date
of
analy-
sis Seam
1 Moisture
Volatile
Proximate
analysis , %
i
£
JZ
in
f
Wyoming
Sweet- Dines
water
n n
n n
n
n
11
n
n
it if
tt it
n n
"
n
11
n
11
it
ti
"
ti
(t n
Sweet- Quealy
water
ti n
Dines
n
n
N
tt
n
n
n
tt
H
n
n
n
n
n
n
M
ft
n
tt
»
Sweet-
water
n
1919
1950
1950
1948
1950
1919
1918
1918
1918
1919
1950
1918
1919
1918
1918
1919
1950
1918
1919
1919
1918
1918
No. 2
1918
No. 15
It
IT
ft
tt
n
n
ti
TI
fl
II
n
u
it
11
n
ti
n
tt
ti
it
Rock
Springs
it
12.0
11.5
11.3
11.1
13.3
11.1
11.3
13.6
11.6
13-9
13.7
15.3
11.8
16.1
13.1
11.8
15.6
15.5
16.0
19.3
18.3
14.2
5.0
11.2
11.7
11.5
11.6
11.7
12.0
12.2
11.2
11.1
11.1
11.7
11.6
12.2
11.0
10.5
10.7
11.1
11.7
11.2
39.7
39.6
12.3
12.9
55.8
51.8
51.6
55.1
55.1
51.2
51.1
55.1
51.5
51.1
51.7
51.8
53-1
51.8
53.3
52.3
52.1
52.6
51.8
51.0
53.7
51.8
52.3
3.0
3-5
3-9
3.3
3.2
3.8
3.7
3.1
1.1
1.2
3.6
3.6
1.1
1.2
6.2
7.1
6.5
5.7
7.0
6.3
6.7
5.9
1.8
Ultimate
analysis, 1
% 1 g
^ * 1
3 £ 8
(continued)
.7 - -
.7 - -
.7 - -
.7 - -
.6 - -
.7 - -
.8 -
.6 - -
.7
.8 - -
.8 - -
.7 - -
.9 - -
.9 5-1 71.0
1.0
1.6
1.3 -
1.1
1.0
1.3 -
1.2
.9 - -
.8 - -
c
g g, Btu
£ &> as Btu
2 o received dry
11,520
11,220
11,200
11,180
11,160
11,330
11,300
11,370
11,130
11,250
11,300
11,160
11,150
1.6 13.9 10,910
- ,. 11,110
- v 10,750
10,730
10,770
10,630
10,220
10,380
12,700
12,820
13,090
13,120
13,070
13,060
13,220
13,190
13,190
13,160
13,030
13,070
13,090
13,170
13,080
13,080
12,790
12,620
12,710
12,710
12,660
12,660
12,700
13,260
13,500
Ash
softening Free
tempera- swelling
ture.P0 index
_
_ _
2,390
_ _
_ _
_ _
_ _
2,230
2,180
_ _
2,230
2,080
2,150
_ _
_ _
2,100
2,160
2,100
2,130
_ _
2,910
Hardgrove
grindability
index
_
_
_
_
_
_
_
_
_
_
_
_
_
_
_
_
_
_
_
_
-
_
-
-------
Table G-l (continued). WESTERN COAL COMPOSITION & PHYSICAL PROPERTIES
Ul
ro
County
Coal
field
or
town
Mine
Narre
Proximate
analysis , 3
1
Date
of
analy-
sis Seam
Moisture
Volatile
9
u
Si
1
Wyoming
Sweet-
water
n
it
n
n
ti
n
"
n
ft
"
ii
ti
ti
tr
tealy
V
Superior
"
ti
ti
11
H
Rock
Springs
n
n
n
it
11
it
Sweet-
water
tt
KLeen-
fVre
n
M
"
ti
n
Peacock
it
11
TI
rt
11
n
1948
1948
1948
1949
19*8
1948
1948
1948
1950
1948
1948
1949
1948
1949
1950
Rock
Springs
n
Nos. 1
& 3
H
n
11
"
tt
Nos. 1
& 7
TI
tt
"
lr
"
It
4.7
7-5
9-2
12.8
10.8
11.3
10.9
11.5
6.3
5-8
5.9
7-1
9.8
6-7
6.4
42.1
42.1
42.4
44.2
44.2
44.4
44.1
42.2
42.9
43.5
42.0
42.0
41.7
41.0
41.4
52.5
52.7
49.3
51.9
53.3
53.7
50.5
51.0
53.4
53-3
53.1
53.7
53-2
52.9
51.6
5-4
5.2
8.3
5.4
2.5
1.9
5.4
6.8
3-7
3-2
4.9
4.3
5.1
6.1
7-0
Ultimate
analysis, %
\ I I
(continued)
.9 - -
1.0
.8 - -
.9 - -
.8
.8 5.4 77.8
.8 -
1.2
1.2
.9 - -
1.0
.9 - -
1.1
1.2
1.2
c
$ | Btu
S x as
z o received
12,740
12,370
11,660
11,550
12,290
1.7 12.4 12,270
11,860
11,600
12,730
12,920
12,690
12,610
11,950
12,390
12,260
Ash
softening Free
Btu tempera- swelling
dry ture ,~?° index
13,370
13,370
12,840
13,240
13,770
13,830
13,310
13,110
13,590
13,720
12,490
13,570
13,250
13,280
13,100
_
2,520
_ _
2,380
2,130
2,710
2,^120
_
_
_
_
_ _
_
-
Hardgrove
grindability
index
_
_,
—
_
_
-
_
_
_
_
_
_
_
_
-
-------
APPENDIX H
PERTINENT CONVERSION FACTORS
BRITISH TO INTERNATIONAL SYSTEM OP UNITS (SI)
553
-------
Table H-l. CONVERSION FACTORS, BRITISH TO SI
To convert from
LT1
acre
British thermal unit (Btu)
British thermal unit/pound-mass (Btu/lb)
Btu/foot2-hour
Btu/hour-foot3
cents/short ton
cents/short ton-mile
degree Celsius (°C)
degree Fahrenheit (°F)
degree Fahrenheit (°F)
dollars/106 Btu
foot (ft)
foot3 (eu ft)
foot2 (sq ft)
gallon (gal)
109 gallons/day (bgd)
gram (gm)
hour (h)
Inch (in)
Inch2 (sq in)
inch3 (cu in)
kilowatt-hour (KWH)
mile (mi)
mile2 (ml2)
minute (mln)
pound-mass/hour
pound-mass Clbm)
ton (long)
ton (short)
watt-hour
yard
yardVshort ton
To
metre2 (m2)
joule (J)
Joule/kilogram (J/kg)
watt/metre2 (W/m2)
watt/metre3 (W/m3)
cents/kilogram (t/kg)
cents/kilogram-metre (i/kg-m)
kelvln (K)
degree Celsius
kelvin (K)
dollars/109 Joules (t/10'J)
metre (m)
metre3 (m3)
metre2 (m2)
metre3 (m3)
metreVsecond (mVs)
kilogram (kg)
second (s)
metre (m)
metre2 (m2)
metre3 (m3)
Joule (J)
metre (m)
metre2 (m2)
second (S)
kilogram/second (kg/s)
kilogram (kg)
kilogram (kg)
kilogram (kg)
joule (J)
metre (m)
metreVkilogram (mVkg)
Multiply by
It. 047 x 103
1.055 x 103
2.324 x 103
3.152 x 10°
1.031 x 101
1.102 x 10~3
6.851 x 10-'
« • * + 273'15
fck - (tf+459. 675/1.8
9.479 x 10-1
3.048 x 10"'
2.832 x 10~2
9.290 x lO"2
3.785 x ID"3
14.381 x 101
1.000 x 10~3
3.600 x 103
2.540 x 10~2
6.452 x 10-11
1.639 x 10-5
3.600 x 106
1.609 x 103
2.590 x 10s
6.000 x 101
2.721 x 102
4.536 x ID'1
1.016 x 103
9.072 x 102
3.600 x 103
9.11|l) x 10-1
8.430 x 10-11
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TECHNICAL REPORT DATA
(Please read fmlructiuns on the reverse before completing)
1. REPORT NO.
EPA-650/2-75-046
3. RECIPIENT'S ACCESSION-NO.
4. TITLE AND SUBTITLE
Evaluation of Low-Sulfur Western Coal Characteristics
Utilization, and Combustion Experience
6. REPORT DATE
May 1975
6. PERFORMING ORGANIZATION CODE
'. AUTHOR(S)
8. PERFORMING ORGANIZATION REPORT NO.
T.E.Ctvrtnicek, S.J.Rusek, and C.W.Sandy
MRC-DA-467
9. PERFORMING OR8ANIZATION NAME AND ADDRESS
Monsanto Research Corporation
Dayton Laboratory
1515 Nicholas Road
Dayton. Ohio 45407
10. PROGRAM ELEMENT NO.
1AB013: ROAP 21BBZ-008
11. CONTRACT/GRANT NO.
68-02-1320, Task 12
12. SPONSORING AGENCY NAME AND ADDRESS
EPA, Office of Research and Development
NERC-RTP, Control Systems Laboratory
Research Triangle Park, NC 27711
13. TYPE OF REPORT AND PERIOD COVERED
Task Final: 5-11/74
14. SPONSORING AGENCY CODE
15. SUPPLEMENTARY NOTES
. ABSTRACT
The repOrt summarizes the data on western coal statistics , combustion, and
mining. Detailed information is presented for coal occurrence, production, compo-
sition, and physical and chemical properties. Discussions and economic analyses are
given of available mining techniques and transportation modes to bring these vast coal
reserves to large fuel combustion markets. The effects of western coal properties on
combustion equipment operation and emissions to the atmosphere are evaluated. The
overall impact of increased western coal production on the environment is also
analyzed and recommendations are made for further investigation of problematic
areas.
7.
KEY WORDS AND DOCUMENT ANALYSIS
DESCRIPTORS
b.lDENTIFIERS/OPEN ENDED TERMS
COSATI Field/Group
Air Pollution
Coal
Sulfur
Sulfur Oxides
Strip Mining
Underground Mining
Land Reclamation
Transportation
Combustion
Air Pollution Control
Low-Sulfur Coal
Western Coal
Coal Composition
Coal Costs
Combustion Experience
Mining Methods
13B
08G, 21D 15E
07B 21B
081
8. DISTRIBUTION STATEMENT
Unlimited
19. SECURITY CLASS (This Report)
Unclassified
21. NO. OF PAGES
570
20. SECURITY CLASS (Thispage)
Unclassified
22. PRICE
EPA Form 2220-1 (9-73)
557
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