EPA-650/2-74-025-a

September 1975
           APPLICABILITY OF THE  MEYERS
                   PROCESS FOR CHEMICAL
              DESULFURIZATION  OF COAL:
           SURVEY OF  THIRTY-FIVE COALS
                              U.S. Environmental Protection Agency
                               Office of Research and Development
                                   Washington. O.C. 20460

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                                   EPA-650/2-74-025-0
APPLICABILITY  OF  THE  MEYERS
     PROCESS  FOR  CHEMICAL
   DESULFURIZATION  OF  COAL:
 SURVEY  OF  THIRTY-FIVE COALS
                    by

           J.W. Hamersma andM.L. Kraft

           Systems Group of TRW, Inc.
                One Space Park
          Redondo Beach, California 90278
             Contract No. 68-02-0647
              ROAP No. 21ADD-096
           Program Element No. 1AB013
        EPA Project Officer:  L. Lorenzi,. Jr.

      Industrial Environmental Research Laboratory
       Office of Energy, Minerals, and Industry
      Research Triangle Park, North Carolina  27711
                Prepared for

      U.S. ENVIRONMENTAL PROTECTION AGENCY
         Office of Research and Development
            Washington, D. C.  20460

                September 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 ap-
 proved  for publication.  Approval does not signify that the contents neces-
 sarily  reflect the views and policies of the Environmental Protection Agency,
 nor does mention of trade names or commercial products constitute endorse-
 ment  or recommendation for use.
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          2.  ENVIRONMENTAL PROTECTION TECHNOLOGY

          3.  ECOLOGICAL RESEARCH

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          7.  MISCELLANEOUS

This report has been assigned to the ENVIRONMENTAL PROTECTION TECHNOLOGY
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                      Publication No. EPA-650/2-74-025-a

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                                  ABSTRACT

     Run-of-mine coal  samples were collected from each of 35 U.S.  mines
located in 13 states from New Mexico and Montana to West Virginia  and
Pennsylvania.  Each coal  was treated separately by the Meyers Process
(ferric sulfate extraction) and float-sink fractionation (physical clean-
ing).  The Meyers Process removed 90-99% of the pyritic sulfur (23-80% of
the total sulfur) from all of the coals which contained sufficient pyritic
sulfur for accurate sulfur determination (i.e., greater than 0.25% w/w).
Fourteen of the coals were reduced to less than 1% total sulfur by the
Meyers Process, while five of the coals were reduced to less than  1%
total sulfur by physical cleaning (1.90 float material, 14 mesh x  0).
With the exception of two mines, the Meyers Process removed significant to
very large increments of sulfur above that quantity which was separable
by physical cleaning.  Significant amounts of Ag, As, Cd, Cr, Cu,  Mn, Ni,
Sb, and Zn were removed along with the pyrite by the Meyers Process, while
float-sink procedures removed significant amounts of Ag, As, Cr,  Cu, F,
Li, Mn, and Zn.
     This report was submitted in fulfillment of Contract Modification No. 1
of Contract 68-02-0647 under the sponsorship of the Office  of Research and
Development, Environmental Protection Agency.
                                     m

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                            TABLE OF CONTENTS

Section                                                              Page
1.0  CONCLUSIONS	    1
2.0  RECOMMENDATIONS	    4
3.0  INTRODUCTION  	    5
4.0  PROGRAM RESULTS	10
     4.1   Summary  .  . >	10
     4.2   Selection, Sampling and Preparation  of Coals	13
          4.2.1  Selection of Coals	15
          4.2.2  Sampling of Coals	18
          4.2.3  Coal and Sample Preparation at  TRW	20
     4.3   Chemical Removal of Pyritic  Sulfur	20
          4.3.1  Experimental Method	21
                4.3.1.1  Extraction Procedure	23
                4.3.1.2  Coal Sampling from Reaction Vessel	24
                4.3.1.3  Precision of Sulfur  Analysis	25
                4.3.1.4  Atomic Absorption Method  for
                         Pyritic Sulfur Determination	26
          4,3.2  Pyritic Sulfur Removal Results  	  29
          4.3.3  Rate of Pyritic Sulfur Removal  	  35
          4.3.4  Heat Content Changes  and  Ferric Ion Consumption.  .  .  39
          4.3.5  Ferric Ion  Consumption as a Function of Time  ....  42
          4.3.6  Removal of  Residual Sulfate	  .  45
          4.3.7  Summary of  Ash Changes 	  50
          4.3.8  Organic Sulfur Changes 	  53
          4.3.9  Miscellaneous Data	62
                                    IV

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                     TABLE OF CONTENTS  (Continued)
Section                                                              Page
     4.4  Float-Sink Testing	    64
          4.4.1   Procedures	    64
          4.4.2   Results and Discussions	    64
     4.5  Removal  of Trace Elements 	    68
          4.5.1   Analysis Procedures and Results	    68
          4.5.2   Removal Efficiencies 	    74
          4.5.3   Summary and Conclusions	    76
5.0  ACKNOWLEDGMENTS	    79
6.0  REFERENCES	    80
7.0  GLOSSARY OF ABBREVIATIONS AND SYMBOLS	    82
8.0  UNIT CONVERSION TABLE	    83
9.0  APPENDICES	    84
     Table of Contents	    84
     Tables	    85
     Figures	    88

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                                   TABLES
                                                                      Page
 1.   Summary of Pyrite Removal  Results	    11
 2.   Initial Coal Selection	    14
 3.   Present Coal Selection	    15
 4.   Coal Analysis Summary - Initial  Fifteen Coals	    16
 5.   Coal Analysis Summary - Present (Final) Twenty Coals 	    17
 6.   Precision of Sulfur Forms  Analysis 	    26
 7.   Determination of Pyritic Sulfur Using Atomic
      Absorption Techniques	    28
 8.   Summary of Pyritic Sulfur Removal  Data 	    30
 9.   Pyritic Sulfur Removal as a Function of Time in Percent. . ...    36
10.   Pyritic Sulfur Removal as a Function of Time -
      % W/W Pyritic Sulfur 	    37
11.   Summary of Heat Content Changes and Excess Ferric Ion
      Consumption	    40
12.   Average Heat Content Losses and Ferric Ion Consumption  ....   42
13.   Ferric Ion Consumption as a Function of Time	   44
14.   Sulfate Content of Treated Coals  	   46
15.   Special Sulfate Removal Experiments - Camp Nos. 1 & 2 Coal  . .   47
16.   Special Sulfate Removal Experiments - Orient No. 6 Coal.  ...   48
17.   Summary of Treated Coal Sulfate Content	   49
18.   Summary of Ash Changes  (% W/W)  	  ....   51
19.   Average Excess Ash Removal (% W/W)	   52
20.   Organic Sulfur Data	   54
21.   Summary of Organic Sulfur  Increments  	   56
22.   Sulfate Determination  on Whole  Coal and  Plasma Ash  	    59
23.   Organic Sulfur Changes with  Ferric Chloride	    59
                                      v1

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                            TABLES (Continued)                         p
24.   Analysis of Leached and Toluene Extracted  Coals  Before
     Vaporization Treatment	   61
25.   Analysis of Extracted Coals from Survey Program  After
     Vaporization Treatment	   61
26.   Miscellaneous Data	   63
27.   Summary of Float-Sink Tests, 14 mesh x 0 Coal, Comparison
     to Meyers Process-, 100 Mesh x 0 Coal	   65
28.   Comparative Trace Element Analysis Results (PPM  in
     Moisture-Free Coal) 	    70
29.   Trace Element Composition of Untreated Coals (PPM)	    72
30.   Trace Element Analytical Precision	    73
31.   Trace Element Removals (% W/W)	    75
                                   VII

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                                  FIGURES

1.  Pyritic Sulfur Removal Process Chemistry	   5
2.  U. S. Bureau of Mines Sampling, Handling System (Amended)	   19
3.  Pyrite Removal as a Function of Time	39
                                    vi 11

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                             1.0   CONCLUSIONS

     1.   Only one of the  thirty-five  run-of-mine  (ROM)  coals  investigated
in this  survey met the  Clean  Air  Act  sulfur  oxide emission  standard of
0.6 Ibs* of sulfur/106  btu  for new stationary  combustion  sources.
     2.   The process for  chemical  removal  of pyritic  sulfur from  coal
(Meyers  Process)  was demonstrated to  remove  (operating  at 100°C):
          a)  90  to 99% of  the pyritic sulfur  (23 to  80%  of the total
     sulfur) from the twenty-three Appalachian Basin  coals  experimentally
     investigated in the  survey program.   An additional coal  obtained
     from the Walker Mine,  contained  insufficient pyritic sulfur, 0.07%
     w/w, for measurable  evaluation in this  program.
          b)  91  to 99% of the pyritic sulfur  (43 to  57%  of the total
     sulfur) from the six Eastern Interior Basin coals  investigated.
          c)  98% of the pyritic sulfur (64% of the total sulfur) from
     the single Western Interior Basin coal  investigated.
          d)  59 to 89% of the pyritic sulfur from the four Western coals
     investigated.  Of these four samples, only coal  from the Colstrip and
     Navajo Mines contained sufficient pyritic sulfur  to give reasonably
     accurate results.
          e)  significant amounts of Ag, As,  Cd,  Cr, Cu, Mn, Ni, Sb, and
     Zn.
     3.  Seven potentially hazardous trace elements -  Ag,  Be,  Cd, Hg, Sb,
Se and Sn -were generally present in the coals  studied  in amounts that
may be only of minimal environmental significance ( <5 ppm)  for effluents
from coal combustion facilities.
     4.  The Meyers  Process reduced  the total  sulfur content of  14 coals
under investigation  to below  1.0%  (eight of these were reduced to 0.75%
or less).
     *EPA policy  is  to express all data in  Agency documents  in metric
units.   Because  implementing  this  practice  will  result in  undue  cost,
NERC/RTP is providing conversion  factors for  the particular  non-metric
units used  in this  document.   These  factors are  located  on page  83.
                                     1

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     5.  The major factor determining the ultimate amount of pyrite
removal in ROM Eastern coals was the top size of the coal.  While 40-50%
of the coals gave 90-99% removal with a 149y (100 mesh)  top size, the
remaining coals had to be reduced to 105y (150 mesh) top size and some to
74y  (200 mesh) top size.  The size reduction also resulted in a substantial
increase in the rate of pyrite removal  so that in most cases, the reaction
time could be reduced from 23 hours to 13 hours or less.
     6.  The rate of pyrite removal was measured as a function of time for
twenty coals, and it was found that the median percentages of removal were
as follows:  68% in 1 hour, 78% in 3 hours, 87% in 6 hours, 90% in 13 hours,
and  94% in 23 hours.
     7.  Most coals showed an increase in heat content after Meyers Process
treatment.  For the Appalachian and some of the Eastern Interior Basin coals,
this heat content rise amounted to 1-11% of the initial heating value.
When calculated on a dry mineral matter free basis, which takes into account
the  ash reduction due to pyrite removal, an average heat content loss of
7 ±2.1% was found for Western coals, Interior Basin coals lost 4 ±1.5%,
and Appalachian coals lost an insignificant 1 ±1.2%.
     8.  Sulfate retention, although variable, was least for Appalachian
coals, averaging 0.09%; intermediate for Interior Basin coals, averaging
0.26%; and high for Western coals.  Reduction of leaching time to
12-14 hours for the Western and Interior Basin coals reduced retention
significantly.
     9.  Ash removal, in addition to that accounted for by pyrite  removal,
was observed in varying degrees for all coals and increased with increas-
ing ash content in the coal.  Excess ash removal was minimal for Appalachian
coals, intermediate for Interior Basin coals, and greatest for Western
coals.
    10.  A single-stage toluene extraction for elemental  sulfur was  found
to be inadequate and in some cases resulted in apparent increases  in
organic sulfur.

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    11.   A vaporization technique at 375°C has been shown to be effective
in removing residual sulfur in those cases where a single stage toluene
extraction has been found to be inadequate.
    12.   Filtration rates were proportional to the amount of ash present
in the coals.  High ash coals filtered significantly slower than low ash
coals.
    13.   Float-sink testing showed that conventional coal cleaning could
reduce the sulfur content of only two of the coals tested to the level
obtainable by the Meyers Process.
    14.   Varying amounts of 18 selected trace metals (see Section 4.5) were
removed by the Meyers Process and by conventional coal cleaning.  The
Meyers Process removed significant amounts (>50%) of Ag, As, Cd, Cr, Mn,
Ni, Sb and Zn, while float-sink procedures removed substantial amounts
(>50%) of Ag, As, Cr, F, Li, Mn, and Zn in the majority of the coals.
Substantial differences were found for Mn and Pb for which the removal
was found to be significantly higher using the Meyers Process, and for
F and Li, where float-sink methods removed significantly greater amounts.
    15.  An atomic  absorption method for the analysis of pyritic sulfur
was developed which has precision and accuracy equivalent to the ASTM
procedure.

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                            2.0  RECOMMENDATIONS

     1.  The Meyers Process should continue to be tested on additional
coals from all parts of the U.S. in order to further define the appli-
cability of the process for meeting legislated sulfur oxide pollution
control standards.
     2.  Future studies should include rate studies concerned with the
removal of pyritic sulfur from various coal size and density fractions
which are typical of the output of coal preparation units, for the pur-
pose of establishing optimum combinations of the Meyers Process with cur-
rent coal handling and treatment practices.
     3.  In order to further define process economics on a wide variety
of coals, the raw rate data obtained and partially treated in Section 4.3.3
should be reduced to kinetic rate expressions and evaluated in greater
detail.
     4.  Process parameters necessary to achieve optimum residual ele-
mental sulfur and sulfate removal, as well as the fate of major acid
soluble ash constituents such as calcium, magnesium and non-pyritic iron,
should be studied.
     5.  Near term emphasis should be placed on Appalachian coals since
the process applicability, as defined by the results from the first coals
leached in this survey, appears to be greatest for this region of the
county, and since 60% of current coal production in the U.S. is mined
in this region.
     6.  Further trace metal analysis should be conducted in order to
determine the conditions of optimum trace metal removal by the combina-
tion of float-sink separation with the Meyers Process.

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                               3.0   INTRODUCTION

      The Meyers  Process  utilizes  a  regenerable aqueous  ferric sulfate
leaching unit  to chemically convert and remove the pyritic sulfur content
of coal  as elemental sulfur and iron sulfate.   In addition, the  ash content
of the  coal is decreased  by 10 to 40% and the  heat content per unit weight
increases by as  much as  11%.   The process chemistry for both leaching and
regeneration is  outlined  in Figure  1.
               CRUSHED COAL IS TREATED WITH FERRIC SULFATE SOLUTION
Fe$? + 4.6
             • 4.8^0 -10.2 FeSC>4
                                                                  0.85
               GENERATED SULFUR IS REMOVED BY VAPORIZATION OR SOLVENT EXTRACTION
               FERRIC SULFATE SOLUTION IS REGENERATED WITH OXYGEN AND EXCESS
               FERRIC AND FERROUS SULFATES ARE REMOVED
                           9.6 FeSO4 ' 4.8H25O4  + 2.4 Oj- 4.8 Fe2 (SO^ * 4.8
                                           IRON
                                           SULFATES
                                                               RECYCLE
                                                               SOLUTION
OVERALL REACTION:
 FeS2 + 2.402- 0.8 S + 0.2
                                                        0.6 FeSO
            Figure 1.   Pyritic  Sulfur Removal Process Chemistry

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     The detailed chemistry, reaction kinetics,  and  engineering  and
economic viability of the process were established under  an  Environmental
Protection Agency sponsored bench-scale program  (Contract No.  EHSD 71-7)
for evaluation of the Meyers Process^'.   Because of the  success of  the
bench-scale program and the national need for sulfur oxide control tech-
nology, the process is now in a pilot plant design phase.
     Other major methods which offer promise for the control  of  sulfur
oxides from coal burning stationary sources include:  flue gas scrubbing,
coal liquefaction, and physical cleaning.   These alternative methods are
compared to the Meyers Process in the following  discussion.
     Chemical desulfurization has some inherent  advantages over flue gas
scrubbing for sulfur oxide control in that:  a)  application  of this  proc-
ess requires no major modification of existing or  new power  plant facil-
ities or of power plant operation, b) sulfur is  removed from coal directly
as elemental sulfur and iron sulfate, and in relatively small amounts (e.g.,
approximately 230,000 tons/yr of these by-products  from  reducing
3.2 x 106 tons/yr of a 4% sulfur coal to 0.8% sulfur, versus 1,000,000 tons/
yr of a gypsum sludge throwaway material  for comparable  sulfur oxide
removal using non-regenerable lime-scrubbing).  This second advantage does
not apply, of course, when comparing the Meyers Process  to the regenerable
flue gas scrubbing processes now under investigation.  The iron sulfates
from the Meyers Process may be converted to an insoluble  basic  iron sulfate
form by calcining, may be used to start up additional process plants, or
may possibly be sold as a chemical product in some locations.
     The Meyers Process has advantages over coal liquefaction in that:
(a) operation under conditions of 100°C to 130°C,  ambient to  100 psig is
possible, while coal liquefaction requires temperatures  of 400-500°C and
pressures in excess of 1,000 psi; (b) a thermal efficiency of greater than
90% is obtained, compared with a thermal efficiency for  coal  liquefaction
of approximately 60-70% (this is an important factor in  the conservation
of the overall U.S. energy base); and (c) only air or oxygen  is  required
as a consumable chemical, while liquefaction requires at least  1 to  2% by
weight hydrogen or synthesis gas and for catalytic  liquefaction, a  signi-
ficant amount of catalyst is found to be unrecoverable.   However, coal

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liquefaction is capable of reducing a broader range of coals to meet air
quality standards.
     The Meyers Process has advantages over physical cleaning (or separa-
tion by physical methods of coal into rock-rich and rock-lean portions)  in
that:  (a) large quantities of waste products are not generated (e.g., for
typical physical cleaning of coal, which is basically conducted to remove
non-combustible rock, 5-10% of the carbon content of the coal is discarded
along with the rock-rich fraction, giving rise to a secondary pollution
problem of acid drainage from tailings.  For deep cleaning of coal, whose
purpose is to remove a large quantity of the pyritic sulfur, up to 30% or
40% by weight of the coal may be discarded, giving rise not only to an acid
drainage problem but to physical and combustion hazards due to the mass of
reject); (b) pollutants are converted into small amounts of potentially
useful chemicals  (e.g., elemental  sulfur and iron sulfate); and (c) con-
sistent and greater reduction in overall pyritic sulfur content can be
achieved.
     Because of the widespread  application of  physical cleaning techniques
for removal of non-combustible  rock  from coal  (which  includes  some  pyrite),
the physical cleaning process deserves  to  be compared directly to the
Meyers Process for applicability  in  meeting the emission  standards  for
sulfur oxides.  Indeed, in actual  practice simple coal washing may  well
be used prior to  the Meyers Process  to  provide an improved  coal product
containing both minimum ash and minimum sulfur, as  well as  optimum  heating
value.
     Therefore, an EPA sponsored  program for a survey of  the "Applicability
of the Meyers Process for  Chemical Desulfurization  of U.S.  Coal"  (Contract
No. 68-02-0647) was established to determine the potential  of the Meyers
Process to desulfurize U.S. coals  and  to establish  a  comparison with
physical cleaning of coal.  It  is  significant  to note that  both  processes
are amenable to simple laboratory  testing:   the Meyers  Process,  through
chemical leaching with ferric  sulfate  solution as described in Figure 1;
and physical cleaning, through  utilization of  float-sink  testing  in dense
media.  In addition, it was a  further  objective of  the  program to  deter-
mine the fate of  minor elements commonly found in domestic  coals  during

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 chemical leaching.   The detailed results  of that  initial survey program
                                                      to)
 were complete in April  1974 and presented in a  reportv  '.  This present
 report covers the results of both the  above-mentioned initial program and
 a contract modification which extended the program scope to include addi-
 tional coal mines.   The detailed data  obtained  in the first program are
 not repeated here.
      The potential  of the Meyers Process  to  provide a means to meet federal
 standards of performance for new stationary  sources is  high.  The Appala-
 chian Coal Basin is an illustrative example.  This coal region has partic-
 ular importance as  it provides 60% of  current U.S. coal production, with
 22 billion tons of  identified and recoverable reserves, and is also the
 major single area of U.S. sulfur oxide air pollution.   Currently, approxi-
 mately 90% of the coal  mined for utility  use  in the Appalachian Basin
 exceeds the sulfur  content required to meet  the sulfur  dioxide emission
 standard of no greater than 1.2 Ibs of SO  emitted per  million btu  of
                                         A
 input energy.  However, predictions made on  the basis of available sulfur
 forms data show that application of the chemical  removal process can
 increase the quantity of Appalachian coal which is capable of meeting
 the performance standard by a factor of four, to  nearly 40%, at 95%
 pyritic sulfur removal.  (Indeed, the  results of  the  survey program to
 date show that eleven of the twenty-three Appalachian coals evaluated
 (48%) were reduced  to 0.6-0.9% w/w sulfur and were consistent with the
 federal  standard.)   In  addition, many  of  the Appalachian coals could
 meet state standards for existing sources using the Meyers Process.
      There are 23 major coal  mining districts in  the  United States having
 several  hundred.identifiable coals, all of which  vary significantly in
 composition;  i.e.,  ash  content,  carbon content, sulfur  content, pyrite
 distribution, etc.   Thus, in order to  establish the applicability of
 chemical  removal  of pyritic sulfur from coal  process  technology for sul-
 fur  oxide pollution control  in the United States, the amount of sulfur
which may be  removed from representatives of the  widest possible variety
of coals  must be  determined.   Consequently,  this  survey program evaluates
20 U.S. additional  coals from mines in the Appalachian  and Eastern Interior
coal basins of the  United States.
                                     8

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     This report of the survey program contains data on over 115 coal
extractions and 540 sets of coal float-sink determinations, necessitating
more than 6,000 separate chemical and spectroscopic analyses.  Therefore,
the following guide is provided for the readers who wish to focus their
attention in a specific area.  Program results are presented in four major
areas:
     •  Selection, sampling and preparation of coals
     •  Chemical removal of pyritic sulfur
     •  Float-sink studies
     •  Evaluation of trace element changes
     These sections are followed by references, a glossary, and appendices.
Those readers desiring to review the experimental data obtained for removal
of pyritic sulfur from coal are directed to Sections 4.1, 4.3 and 4.4
(p. 10, 20, and 64, respectively), as well as  to the appendix tables cited
in these sections.  Those readers desiring the selection criteria of coals
for the survey are directed to  Section 4.2, while those readers  interested
in experimental methods and sample techniques  and preparation are directed
to Sections 4.2 and 4.3 (p. 13  and 20, respectively).   Float-sink (wash-
ability) studies are reported in Section 4.4  (p. 64) and the trace  element
studies are presented in Section 4.5  (p.  68).

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                            4.0  PROGRAM RESULTS

      The program results are presented in the five sections to follow:
 (1) Summary, (2) Selection, Sampling and Preparation, (3) Chemical Removal
 of Pyritic Sulfur,  (4)  Float-Sink Testing, and (5) Removal of Trace Ele-
 ments in Coal.
 4.1  SUMMARY
      The Meyers Process is  operable over a wide range of conditions (e.g.,
 100°C-130°C, coal top sizes of 1/4" to 200 mesh x 0, pressures from ambient
 to 100 psig, and both with  and without concurrent regeneration of leach
 solution).  Detailed discussions of the data obtained utilizing these
 variations are  presented in separate reports covering the bench-scale
         fl 3}
 programsv ' '.
      A set of reaction  conditions amenable to laboratory testing which are
 within the above range  of variables was selected for this survey program.
 More specifically,  testing  was  conducted at approximately 100°C and ambient
 pressure, and the leach solution was periodically changed in order to main-
 tain reasonable reaction rates.  Each coal was found to require specific
 conditions for  maximum  pyrite  removal and total sulfur content reduction
 relative to one or  more of  the  following factors:  reaction time, coal
 particle size,  degree and type  of washing for sulfate removal, and excess
 utilization of  ferric ion.   More than one reaction trial was often neces-
 sary for identification of  the  conditions for high pyrite removal.
      A summary  of the best  results to date for chemical removal of pyritic
 sulfur and the  optimal  results  for conventional coal washing (float-sink
 evaluation)  are shown in Table  1 in terms of total sulfur changes.  The
 table describes the results obtained on coals which contained sufficient
 pyritic  sulfur  for  accurate sulfur removal determination  (i.e. >0.25% w/w).
 The Edna, Belle Ayr, and  Walker mines were below this limit and therefore do
 not  appear in the table.  Actual total sulfur values before and after chem-
 ical  removal  are shown  in Columns 4 and 5.  These may be  compared with
Column 6,  which shows sulfur values which could be obtained for full  proc-
ess optimization  (at 95% pyrite removal with no increase  in starting
                                    10

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                                                 Table 1
                        SUMMARY  OF  PYRITIC SULFUR  REMOVAL RESULTS
Mine
Navajo
Seam
Nos. 6, 7 & 8
Kopperston No. 2 Campbell Creek
Harris Nos. 1 &
Colstrlp
Warwick
Marion
Matnies
Isabella
Orient No. 6
Lucas
Jane
Marti nka
North River
Humphrey No. 7
NO. 1
Bird No. 3
Williams
Siioemaker
Meigs
Fox
Dean
Powhattan No. '
Eagle Wo. 2
Star
Robinson Run
Homestead
2 Eagle & No. 2 Gas
Rosebud
Sewickley
Upper Freeport
Pittsburgh
Pittsburgh
Herri n No. 6
Middle Kittanning
Lower Freeport
Lower Ki ttanni ng
Corona
Pittsburgh
Mason
Lower Kittanning
Pittsburgh
Pittsburgh
Clarion 4A
Lower Kittanning
Dean
Pittsburgh No. 8
Illinois No. 5
No. 9
Pittsburgh
No. 11
Camp Hos. 1X2 No. 9 (W. Ky. )
Ken
Delirant
Muskingurn
Weldon Ho. 11
Eqypt Valley
No. 21
No. 9
Upper Freeport
Meigs Creek
Des Moines ho. 1
Pittsburgh Ho. 8

State
N. Mexico
W. Virginia
W. Virginia
Montana
Pennsylvania
Pennsylvania
Pennsylvania
Pennsylvania
' Illinois
Pennsyl vani a
Pennsylvania
W. Virginia
Alabama
W. Virginia
E. Kentucky
Pennsylvania
W. Virginia
W. Virginia
Ohio
Pennsylvania
Tennessee
Ohio
Illinois
W. Kentucky
W. Virginia
W. Kentucky
W. Kentucky
W. Kentucky
Pennsylvania
Ohio
Iowa
Ohio

I Total Sulfur w/w in Coala
Initial
0.8
0.9
1.0
1.0
1.4
1.4
1.5
1.6
1.7
1.8
1.8
2.0
2.1
2.6
3.1
3.1
3.5
3.5
3.7
3.8
4.1
4.1
4.3
4.3
4.4
4.5
4.5
4.8
4.9
6.1
6.4
6.6

After Meyers Process
Current Results
0.6
0.6
0.8
0.6
0.7
0.7
0.9
0.7
0.9
0.6
0.7
0.6
0.9
1.5
1.6
0.8
1.7
1.7
1.9
1.6
2.1
1.9
. 2.0
2.5
2.2
2.4
2.0
2.8
1.0
3.2
2.2
2.7

95% Removal
0.5
0.5
0.5
0.7
0.3
0.5
0.5
0.6
0.4
0.4
0.5
0.7
0.7
1.1
1.2
0.4
1.4
1.4
1.6
0.8
1.6
1.7
1.8
1.9
1.6
1.5
1.8
2.1
0.6
2.6
1.4
1.7

Meyers Process
PyrUe
Conversion
% w/w
90
92
94
83
92
96
95
96
96
94
91
92
91
91
90
96
96
96
93
93
94
99
94
91
97
93
99
91
96
"4
92
93

Meyers Process
Total Sulfur
Decrease
% w/w
25
33
23
30
54
50
36
54
44
64
63
70
55
42
48
75
50
51
48
57
49
53
54
43
50
47
55
42
80
47
65
59

% Sulfur (n Coalb
After Float-
Sink
	
0.8
0.9
...
1.0
1.2
1.7
1.5
1.4
0.7
0.8
0.8
2.2
1.9
2.3
1.6
2.3
3.6
2.8
2.0
3.0
3.3
2.9
3.0
3.0
3.2
2.9
3.5
2.1
4.4
3.9
4.6

Dry, moisture-free basis.
1.90 Float material, 14 mesh x  0, is defined here as
                                             the limit of conventional coal
°Sulfur content of coal at 95% pyrite removal and no increase in sulfate or measured
cleaning  (See Section 4.4)
organic sulfur content.

-------
 sulfate or measured organic sulfur content).  Thus, for example, although
 99% pyrite conversion was obtained for the Camp Nos. 1 and 2 mines, the
 total  sulfur was reduced to 2.0%, not the theoretical 1.8%, due to a slight
 measured increase in other sulfur forms.
      Because of the widespread application of physical cleaning techniques
 for removal of non-combustible rock  (which includes varying amounts of
 pyrite) from coal (along with some carbon), float-sink fractionation was
 performed in order to define the relative utility of washing and chemical
 desulfurization for each coal.  The results which are shown in Table 1,
 indicate that:   a) the Meyers Process, at its current state of development,
 removed 83-99% of the pyritic sulfur content of the 32 coals studied,
 resulting in total sulfur content reductions of 25 to 80%, b) eleven (34%)
 of the coals were reduced in sulfur content to the 0.6 - 0.8% sulfur levels
 generally consistent with the federal standard for new stationary sources
 and many state standards,  c) in all  cases, the Meyers Process removed sig-
 nificant to very large increments of sulfur over that separable by physical
 cleaning, and d) in one case, the Mathies mine, coal cleaning resulted in
 a  sulfur content increase.
      State emission regulations for discharge of sulfur oxides from utility
 and large industrial  power  plants can also be met by application of the
 Meyers Process.   For example, the Pennsylvania state standard for eight
 air basins is approximately  1.1% sulfur, for coal of 25 x 106 btu/ton.
 Several  of the  tested Pennsylvania coal  mines (Marion, Mathies, Isabella,
 Bird No.  3 and  Delmont)  meet this standard after chemical desulfurization
 but do not meet the standard after efficient physical cleaning.  These
 coals  could also be transported to Michigan, New Jersey or New York to
meet their state standards  of approximately 1.0% and 1.8% and 2.4% sulfur,
 respectively.   Two of the Ohio coal  mines (Meigs and Powhattan No. 4) would
meet the  "28 county standards" of approximately 2% sulfur for the state of
Ohio after treatment by the Meyers Process, whereas efficient cleaning of
these  coals  reduces their sulfur content to only 2.8% and 3.3%,
respectively.
     The  Orient  No.  6 mine  of Illinois meets the Chicago area standard of
1.29% sulfur  after chemical desulfurization but does not meet the standard
                                    12

-------
after physical cleaning.  The Camp Nos. 1 and 2 mines in Western  Kentucky
meet the state standard for "Priority 3" regions of less than 2.3% sulfur
after treatment by the Meyers Process, whereas physical  cleaning  reduces
the total content of this coal to 2.5%.  The Humphrey No. 7 mine  is
reduced to 1.5% sulfur, which meets the West Virginia standards for
"Regions 2 and 3" of 1.7 and 2%,respectively, whereas physical cleaning
reduces the sulfur content to 1.9%.  The Wei don mine in  Iowa is reduced
to 2.3% sulfur by the Meyers Process which meets the state requirement of
approximately 3.1% sulfur.  Physical cleaning does not meet the standard,
reducing the sulfur content to 3.8%.
     Process improvements, such as more efficient residual sulfur and sul-
fate removal, will cause most coals to be further reduced in sulfur content
to the "95% removal" level shown in Column 6 of Table 1.
     In the production of clean fuel using commercial practices,  it is
very likely that an optimum process cost and product will be obtained by
physically cleaning coal prior to ferric sulfate leaching, in order to
remove rock and some of the larger pyrite particles.  There are prelimi-
nary indications that the efficiency of the Meyers Process may be enhanced
by utilization of physically cleaned coal,  resulting in  faster rates,
greater total removal, and reduced ash dissolution.
     Results from this chemical desulfurizaton survey also showed that
silver, arsenic, cadmium, chromium, copper, manganese, nickel, antimony,
and zinc could be substantially removed from many of the coals during
the Meyers Process treatment.
     The detailed results are presented in  the following five sections
and in the cited Appendix divisions.
4.2  METHODOLOGY OF SELECTION, SAMPLING AND PREPARATION  OF COALS
     TRW selected thirty-five coal mines which were sampled  in two groups.
The data obtained for the first group of fifteen mines has already been
reported^ ', but will be included in summary form in this report,  in order
to substantiate correlations and conclusions drawn from  the data for all
the coals.  The data obtained in the second group of twenty mines  is new
                                    13

-------
and is  completely reported herein.   The mine selections were made on the
basis of  the following criteria:
           a)  Representation of the  widest possible variety of coal  beds,
     coal  regions, and coal rank;
           b)  High production and  reserves;
           c)  Sulfur content in coal  sufficiently high  to require control
     of sulfur oxide emissions from  combustion.
                                                                       (4)
     The  selected mines, the annual  production of each  mine in 1972V   ,
and the analysis summary of each group of coal samples  are given in
Tables  2, 3, 4, and 5.  The following sections present  a  summary of the

                                  Table 2
                                    GROUP 1
                            INITIAL  COAL SELECTION

CATEGORY

c;
*n
~(S
0 •—
U 10
o
in (_>
o c
c *o
E -c
3 0
CD  0> C
V) C t/l
3 — . ID
IE"
E 0) "0
3 *-> O
i-
<— 0
O k-
c_> &> C
3 •—  a) wi
3 *J •—
0 ••- *J
ceo
^ — 1 C
-•- «0 HJ
CO *J
1 f— I/>
3 O 3
t/1 
-------
                                   Table 3
                                   GROUP 2
                           PRESENT COAL SELECTION

CATEGORY


••-
CO

o
o
c
n
.c
 « -t-> CO
••- O C
CO (_}•—•

STATE
Ohio
East Ohio


Pennsylvania
Pennsylvania
West Virginia
West Virginia
West Virginia
Pennsyl vani a

Pennsylvania
Ohio
Pennsylvania
West Virginia
Ohio
Tennessee
West Virginia

West Virginia

Alabama
West Kentucky
West Kentucky
West Kentucky



COUNTY
Meigs
Monroe


Fayette
Washington
Marion
Harrison
Marshall
Westmoreland

Indiana
Columbi ana
Somerset
Logan
Meigs
Scott
Wyoming

Boone

Jefferson
Ohio
Ohio
Hopkins



MINE
Muski ngum
Powhattan No. 4


Isabella
Mathies
Williams
Robinson Run
Shoemaker
Delmont

Mari on
Lucas
Bird No. 3
Marti nka
Meigs
Dean
Kopperston No. 2

Harris Nos. 1 i 2

North River
Homestead
Ken
Star



SEAM
Meigs Creek No. 9
Pittsburgh No. 8


Pittsburgh
Pittsburgh
Pittsburgh
Pittsburgh
Pittsburgh
Upper Freeport

Upper Freeport
Middle Kittanning
Lower Kittanning
Lower Kittanning
Clarion 4A
Dean
Campbell Creek

Eagle 8 No. 2 Gas


No. 11
No. 9
No. 9


1972 Production
000 Tons
4,310
691


722
2,205
1,045
n.a.*
1,643
426

436
n.a.
955
n.a.
n.a.
60
1,332

1,718


2,469
1,536
1,494



COMPANY
Central Ohio Coal Company
Quarto Mining Company, Sub-
sidiary of North American
Coal Company
National Mines Corporation
Mathies Coal Company
Consolidation Coal Company
Consolidation Coal Company
Consolidation Coal Company
Eastern Associated Coal
Corporation
Tunnel ton Mining Company
Buckeye Coal Mining Company
Island Creek Coal Company
American Electric Power Company
American Electric Power Company
Royal Dean Coal Company
Eastern Associated Coal
Corporation
Eastern Associated Coal
Corporation

Peabody Coal Company
Peabody Coal Company
Peabody Coal Company


*Not currently available.
 rationale for selection, a description of the sampling of the coals, and a
 discussion of sample preparation for testing at TRW.  A detailed discussion
 of the coals and mines selected and maps showing the geographic distribu-
 tion of the mines and seams are given in Appendix A.
 4.2.1  Selection of Coals
      Using the above criteria, a total of twenty-four of the mines was
 selected from the Appalachian Coal Basin.  This large number was chosen
 since nearly 70% of current U.S. production comes from this region, and
 272 x 109 metric tons (300 x 10  tons) of reserves  (800 years supply at
 current production) still exist, although only 10-15% of the coal now
 mined can meet the federal standards for new stationary sources.  Further-
 more, much of the coal is high in pyritic sulfur, thus making it amenable
 to treatment.  This coal is also closest to the major markets.  The mines
 (Tables 2, 3, 4, and 5) were selected to represent a wide geographic
                                     15

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                                  Table 4
                           COAL ANALYSIS SUMMARY
                           INITIAL FIFTEEN COALS^

Mine


Warwick
Egypt Vallej
No. 21
Humphrey
No. 7
Fox

Walker

Jane
Nos. 1 S2
No. 1
Eagle No. 2
Camp Nos. 1
and 2
Orient No. 6
Wei don
Edna
Navajo
Belle Ayr
Colstrip

Seam


Sewickley
Pittsburgh
No. 8
Pittsburgh

Lower
Ki ttanning
Upper
Ki ttanning
Lower
Freeport
Mason
Illinois No. 5
Seam No. 9

Herrin No. 6
Des Hoines
No. 1
Wadge
Nos. 6,7,8
Roland-Smith
Rosebud
As Received
Ba 1s

Rank

hvAb
hvAb

hvAb

hvAb

Ivb

hvAb

hvAb
hvAb
hvBb

hvAb
hvCb
hvCb
hvCb
sub A
subB
Moisture

X w/w
1.50
2.07

1.63

1.83

2.07

1.17

2.22
3.31
3.99

3.51
13 29
8.41
11.07
19.14
20.41
Dry Forms of Sulfur, % w/w

Total

1.37
6.55

2.58

3.83

0.71

1.85

3.12
4.29
4.51

1.66
6.39
0.75
0.81
0.76
1.01

Pyritic

1.09
5.07

1.59

3.09

0.07

1.44

1.98
2.64
2.80

1.30
5.24
0.14
0.28
0.22
0.34

Sulfate

0.01
0.14

0.01

0.05

0.00

0.00

0.08
0.04
0.06

0.01
0.15
0.00
0.03
0.03
0.00

Organic

0.27
1.34

0.98

0.69

0.64

0.41

1.06
1.61
1.65

0.36
1.00
0.61
0.50
0.54
0.67
Dry Proximate Analysis, % w/w

Ash

40.47
25.29

9.88

13.55

16.67

21.75

11.39
26.53
21.13

22.51
15.74
9.13
25.29
7.55
10.38

Volatiles

27.77
36.12

37.66

38.33

18.89

30.07

38.91
34.30
35.86

31.67
40.62
40.65
35.51
47.11
43.09
Fixed

Carbon
31.76
38.59

52.46

48.12

64.44

48.18

49.70
39.17
43.01

45.82
43.64
50. qq
39.20
45.34
46.53
Heat
Content
btu
8612
10594

13631

12973

12602

11932

13054
10566
11105

11163
11760
11246
10050
12034
11591
  For a complete set of data, see Reference 2.

distribution  of  the  seams and those having  large  reserves  and high produc-
tion  (Kittanning, Pittsburgh, and Freeport), with a  lesser effort being
made  to get a wide selection of stratigraphic  groups.   From a stratigraphic
standpoint, these mine  selections range from the  Sewickley Seam,  which is
relatively young, to the  Eagle and No. 2  Gas Seams,  which  are relatively
old.
      A group  of  six  coals  was  selected from the Eastern Interior Coal
Basin representing the  Illinois No. 5  (Kentucky No.  9), and the Illinois
(Herrin) No.  6 (Kentucky  No. 11)  seams.   Less  emphasis was placed on this
region due to its smaller production and  the fact that the generally higher
organic sulfur contents (1.5-2.5%) of  these coals make them less able to
meet  pollution control  standards  by pyritic sulfur removal alone.
                                     16

-------
                                  Table 5
                          COAL ANALYSIS SUMMARY9
                       PRESENT (FINAL) TWENTY COALS

Mine

Muskingum

Powhattan
No. 4
Isabella
Mathies
Williams
Robinson
Run
Shoemaker
Delmont

Lucas

Bird No. 3

Marti nka

Meigs
Dean
Kopperston
No. 2
Harris
Nos. U2

Homestead
Ken
Star

Seam

Meigs Creek
No. 9
Pittsburgh
No. 8
"ittsburgh
Pittsburgh
Pittsburgh
Pittsburgh

Pittsburgh
Upper Freeport

Middle
Ki ttanning
Lower
Ki ttanning
Lower
Ki ttanning
Clarion 4A
Dean
Campbell Creek
Eagle & No. 2
Gas

No. 11
No. 9
No. 9
As Rec
Bas
Rank

hvAb

hvAb

hvAb
hvAb :'
hvAb
hvAb

hvAb
hvAb

hvAb

Ivb

hvAb

hvBb
hvAb
hvAb
hvAb

hvAb
hvBb
hvBb
hvBb
elved
Moisture
X w/w
3.36

2.10

1.57
2.15
1.28
0.96

1.51
0.77
1.84
3.88

0.84

1.84

4.77
1.06
1.38
1.72

1.57
5.41
4.76
6.13
Dry Forms of Sulfur, % w/w
Total

6.08

4.12

1.57
1.46
3.48
4.38

3.51
4.89
1.37
1.79

3.14

1.96

3.73
4.09
0.91
1.00

2.06
4.46
4.83
4.32
Pyr1 ti c

3.65

2.57

1.07
1.05
2.23
2.89

2.19
4.56
0.90
1.42

2.87

1.61

2.19
2.62
0.47
0.49

1.42
3.11
2.85
2.60
ulfate

0.06

0.19

0.04
0.04
0.04
0.06

0.05
0.08
0.02
0.05

0.05

0.09

0.06
0.15
0.03
0.03

0.07
0.10
0.26
0.24
Organic

2.37

1.36

0.46
0.37
1.21
1.43

1.27
0.25
0.45
0.32

0.22

0.26

1.48
1.32
0.41
0.48

0.57
1.25
1.72
1.50
Dry Proximate Analysis, % w/w
Ash

21.68

37.17

42.22
41.01
13.18
13.36

33.48
27.18
26.40


30.23

49.64

26.53
17.28
30.15
18.63

49.25
16.56
15.08
13.90
olatiles

36.36

29.01

24.69
24.53
38.64
38.88

31.13
28.33
24.45
35.30

16.18

21.60

34.92
36.91
23.89
26.86

23.19
33.14
35.26
33.94
Fixed
Carbon
41.96

33.82

33.09
34.46
48.18
47.76

35.39
44.49
49.15
56.02

53.59

28.76

38.55
45.81
45.96
54.51

27.56

49.66
52.16
Heat
ontent
btu
11014

8603

8216
8154
13013
12962

9495
11012
11046
13451

10550

7552

10246
12107
10957
12414

7693

12099
12308
 For a complete set of data, see Appendix C.
     A single sample from  the  Weldon  Mine,  Des Moines No. 1 Seam, was
chosen from the Western  Interior Basin.
     A group of four coals was selected  from the remaining coal basins in
the western half of the  United States.   Even though this area contains
more than half of all  U.S. reserves,  the selections were deliberately
limited because of present low production,  sulfur contents generally
less than 1.0%, and pyritic sulfur contents so low (<0.25%) that the
results of chemical extraction would  be  difficult to measure.
                                     17

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 4.2.2  Sampling of Coals
      Samples containing 908  kg  (one ton) of raw run-of-mine (ROM) coal
 were collected from each mine.  The samples were taken in increments that
 represented at least a half  day's production.  Samples were collected in
 accordance with ASTM Standard D2234* ' with the following preferences:
 automatic samples,  stopped belt increments, and, if necessary, full fall-
 ing stream intercepts.  Auger sampling of unit trains in certain instances
 was also  utilized in cases where it could be shown that the trains con-
 tained  only ROM coal from a  single seam and mine.
      The  samples were sealed in plastic-lined drums (six per mine) for
 shipment  to Commercial Testing and Engineering Laboratory (CT&E) where
 each  908  kg (one ton) gross  sample was crushed to 38.1 mm x 0  (1-1/2" x 0)
 by  a  jaw  crusher, divided into four parts and treated as follows:
      •  A 38.1 mm x 0 (1-1/2" x 0) fraction was taken for float-sink
        fractionalion,
      •  A second part was crushed to 9.51 mm x 0 (3/8" x 0) for float-
        sink fractionation,
     •  A third part was crushed to 1.41 mm x 0 (14 mesh x 0)  for float-
        sink fractionation.  An 11 kg sample of this material  was also
        sent to TRW for chemical processing to remove pyritic  sulfur.
     •  The remaining part was held in reserve.
     Float-sink fractionation of portions 1, 2 and 3 above was performed
with organic liquids at 1.30, 1.40, 1.60 and 1.90 specific gravities.  The
resulting fractions were analyzed for ash, total sulfur, and pyritic sul-
fur on a dry basis.  The results were then used to calculate washability
tables in order to determine cumulative recoveries and rejects at the
various specific gravities.  Figure 2 illustrates the sequence of sampling
and testing.
     The procedures used to collect each of the current twenty 908 kg
samples are described in Appendix A, while the procedures used for the
initial  fifteen coals have been reported previously
                                    18

-------
                                            R.O.M.
                                     SAMPLE - 908 KG. (2000 LBS)
                                    LINED 200 L (55 GAL) DRUMS
                                      SHIPPED TO C.T.&E. LAB.
                               CRUSHED TO 38.1 MM (1-1/2") TOP SIZE
                                         JAW CRUSHER
           1/4 OF SAMPLE
OVERSIZE      SCREEN
           9.51 MM (3/8")
                                         1/4 OF SAMPLE
                                 1/4 OF SAMPLE
              FINES
                               CRUSHED TO 9.51 MM (3/8") TOP SIZE
                                      IMPACT CRUSHER
OVERSJZE    SCREEN        OVERSIZE
   ~"    1.41 MM (14 MESH)
              FINES
OVERSIZE     SCREEN       OVERSIZE
          149M (100 MESH)
              FINES
          CHEM. ANAL.
         T.S.,PY. S., ASH
      FLOAT-SINK ANAL.
        SP.GR.  1.3
               1.4
               1.6
               1.9
        140 KG. USED
   SCREEN
  1.41 MM (14 MESH)
                                            FINES
      SCREEN
  149M (100 MESH)
                                            FINES
   CHEM. ANAL.
   T.S.,  PY.S.,ASH
FLOAT-SINK ANAL.
 SP.GR.  1.3
        1.4
        1.6
        1.9
  70 KG, USED
                            CRUSHED TO-1.41 MM (-14
                            MESH)   HAMMER MILL
1.41 MM (-14 MESH)
                                                              TRW
                                                             SAMPLE
                               FLOAT-SINK ANAL.
                                 SP. GR.  1.3
                                         1.4
                                         1.6
                                         1.9
                                    3 KG. USED
                          1/4 OF SAMPLE
                            (RESERVE)
         Figure  2.   U.S.  Bureau  of Mines  Sampling,  Handling  System
                         Amended
                                                    19

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4.2.3  Coal and Sample Preparation at TRW
     An 11 kg (25 1b) sample of coal  ground to 1.41  mm x 0 (14 mesh  x  0)
was shipped from CT&E to TRW in a sealed polyethylene bag inside a
5-gallon can.  If any surface moisture was observed  upon receipt at  TRW,
the coal was spread on a polyethylene sheet in a fume hood and allowed to
air dry from 4 to 6 hours.   This gross sample was then reduced by riffling
to obtain 1600-2000g portions.  One sample was stored under nitrogen or
argon in a glass container as a reserve, and another was ground in  a dis-
integrator with a 0.58. mm screen.  After several passes, the entire lot
was sieved using a 149y (100 mesh) screen.  All oversize material was then
passed through the grinder several more times and resieved; this process
was repeated until more than 99% of the material passed through a 149y
(100 mesh) screen.  The remaining fraction of 1%, which was composed of
slate and other rock-like material, was discarded.  The entire lot of
149y x 0 (100 mesh x 0) coal was then thoroughly mixed by conventional
cone and quartering techniques on a polyethylene sheet.  The coal was
then bottled as 100.0 g samples in containers that had been flushed with
nitrogen or argon.  In order to guarantee relatively uniform samples, the
coal was periodically mixed during this process.  It was found that when
the coal was 100% 149y x 0 (100 x 0 mesh), in most cases 91% would pass a
105y (150 mesh) screen and 70% would pass a 74y  (200 mesh) screen.
     If finer coal was needed, the required amount of coal (200-300g) was
quantitatively ground in a ball mill to pass a  105y  (150 mesh) or 74y
(200 mesh) screen.
4.3  CHEMICAL REMOVAL OF PYRITIC SULFUR
     This section presents descriptions of the  experimental methods and
summarizes results from the studies involving chemical  removal of pyritic
sulfur from the surveyed coals.  The removal of  trace elements from coals
as a result of the Meyers Process  is described  in Section 4.5, together
with a discussion of the experimental methods  used to determine  the trace
element composition.
     Also  included  in  this section are  discussions of:   (a) total pyritic
sulfur  removal and  its  removal  as  a function  of time,  (b)  ferric ion
                                    20

-------
consumption and its relationship to pyrite removal  and  the  final  heat
content of coal, (c) ash changes, (d) sulfate retention,  (e)  changes
in the organic sulfur content, and (f) miscellaneous findings.
4.3.1  Experimental Method
     The reaction conditions for pyritic sulfur removal have  been adapted
                                                          (1  3)
from the previous bench scale studies (Contract EHSD 71-7)v ' '  and the
                           (2\
previously completed Part Iv ' of the survey program, for the purposes of:
(a) obtaining 90-100% pyritic sulfur removal, (b) simulating  process design
as nearly as possible, and (c) obtaining as much quantitative data as pos-
sible.  The general procedure is discussed below.
     Mesh Size — Coal ground to 100 mesh x 0 was found to give the maximum
extraction rates and to be most satisfactory for laboratory scale sampling.
Coal ground to a finer mesh was used only if conditions warranted.
     Ferric Ion Concentration - Ferric sulfate solution IN in ferric ion
appears to be optimum, although differences due to concentration changes
                         (1 3)
do not appear to be greatv '  .
     Reaction Temperature — The reaction temperature was held at the
reflux of 1 N ferric sulfate solution, which is approximately 102°C.
This allows a reasonably high reaction rate and yet did not require
pressure equipment.
     A trial experiment was run for each coal (due to  the  high variance
in the behavior of individual coals)  in order to select the reaction time,
mesh size, and number of leach solution changes needed for maximum pyrite
removal.
     Reaction Time - Each coal was leached a total of  six  or more  hours,
depending on the characteristics of the individual coal being treated.
     Ferric Ion to Total Iron Ratio - Since the rate of pyrite removal  is
slowed substantially by ferrous ion accumulation,  each coal was  treated
under conditions designed to keep this ratio >0.80 by  one  of the  following
methods:
     •  Increasing the solvent to coal ratio (w/v) from a  nominal  3 to  8
        used in the bench scale work  to 25.
                                    21

-------
     •  Changing the leach solution after 3 to 6 hours of reaction or
        more often, if required.
     0  A combination of the above.
     Post Sample Treatment — After treatment, the samples were thoroughly
washed to remove any residual leach solution.  The wet coal was extracted
with toluene to remove elemental sulfur, and then dried.  All sample cal-
culations were done on a dry basis in order to eliminate variables due to
wetness of the coal.  Sulfur forms and proximate analysis were obtained
for each treated coal  sample.
     In addition to the characterization of the initial and treated coal,
further evaluations were performed on the 20 additional coal mines sampled
for this part of the survey,  in order to determine in greater detail the
kinetic behavior of pyritic sulfur extraction and at the same time, to
investigate potential  problem areas that may arise when the Meyers Process
is applied to a large  variety of coals.  This included an evaluation of the
following items for all  coal  samples processed:
     Rate of Pyrite Removal - Coal samples were taken periodically and
analyzed for pyritic sulfur.   In order to simplify rate calculations, the
ratio of coal  to leaching solution was kept constant by always withdrawing
an equivalent amount of leach solution.
     Rate of Ferric Ion Consumption — The leach solution withdrawn from
the above samples was  analyzed for ferrous as well as total  iron in order
to determine the rate  of ferric ion consumption and iron balance.  Addi-
tional  samples were withdrawn and analyzed as necessary in order to get
precise results.
     Retention of Leach Solution on the Coal - Retention of the leach solu-
tion on the coal was determined by weighing the coal after filtration under
a set of standardized  conditions and subtracting the dry weight of the
treated coal.
     Retention of Sulfur Solvent — Retention of the sulfur solvent on the
coal was determined by weighing the coal after filtration under a set of
standardized conditions and subtracting the weight of the treated coal.
                                    22

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4.3.1.1  Extraction Procedure

     The exact procedure used in this survey is described  below:

          One hundred grams of 100 mesh x 0 coal are added to  2  £
     refluxing IN ferric sulfate solution contained in a 4-necked,
     3 I glass cylindrical reaction vessel equipped with a mechanical
     stirrer, reflux condenser and a thermocouple attached to  a
     recorder.  Each vessel also has a stopcock at the bottom  for
     taking samples and is heated by a specially constructed heating
     mantle.  After the coal addition, an additional 0.5&1N ferric
     sulfate solution is used to wash down the sides of the vessel.
     At this point, the to solution sample is taken and the leaching
     process is considered started.  Then, the reaction mixture,
     which is at 88 ±4QC, is rapidly brought to reflux, a process
     that takes 8-12 minutes.  Leach solution samples for each
     analysis are collected by taking a 35 ml aliquot of the reaction
     mixture (the sampling procedures are discussed below) and cooling
     it immediately to 0°C.  After cooling, the aliquot is centrifuged
     to remove all suspended solids and 30 ml of this is used for  iron
     analysis.  The remaining coal is washed, dried and saved for
     pyritic sulfur analysis.

          After 4-6 hours, the heating is stopped and the reaction
     mixture is drained from the flask, filtered and dewatered under
     vacuum conditions.  The final reaction volume and solution reten-
     tion on the coal are determined at this time.  The wet, unwashed
     coal is slurried with 200 ml fresh ferric sulfate solution at
     30°C and added to 2 ifresh IN ferric sulfate solution at reflux.
     Another 300 ml ferric sulfate is then used to wash any residual
     coal into the flask.  A to leach solution sample is taken imme-
     diately and the entire reaction mixture is brought to reflux in
     8-12 minutes.  Leach solution samples are taken at regular
     intervals; and after a total elapsed reacton time of 10 to
     24 hours, the reaction mixture is drained from the reaction
     flask, filtered and washed clear with 0.5 - l.OHwater.

          The extracted coal is then slurried with 2£0.2N H2S04 at
     *• 80°C.  This is followed by slurrying in 2iwater.  If schedul-
     ing does not permit the coal to be extracted with toluene imme-
     diately, it is stirred at^50°C in water for an extended period
     until it can be filtered and extracted.

          After the extraction of residual sulfate and iron, the wet
     coal is transferred into a 1«, round bottom flask equipped with a
     mechanical stirrer and Dean-Stark trap.  Toluene, 400 ml,  is
     added and the mixture is brought to reflux.  This is continued
     until all the water is azeotroped off  (approximately 0.75  -
     1.25 hour and 50 - 75 ml) plus another 15 minutes.  The hot
     solution is then filtered, washed with 50  - 75 ml toluene, and
     dried in a vacuum oven at 100 - 12QOC.  The coal  is then weighed
     and analyzed.
                                     23

-------
 4.3.1.2  Coal Sampling from Reaction  Vessel
      In order to determine the rate of  pyrite removed from the coal,  it is
 necessary to periodically take coal samples from the reactor for pyrite
 analysis.  This is because the accumulation of ferrous ion in solution
 reflects not only the oxidation of pyrite but also a small and variable
 reaction with the organic matter in coar ' * '.
      Initially,  it was thought that,  since 100 mesh x 0 or finer coal was
 being used,  the coal  distribution within the rapidly stirred and boiling
 reactor would be uniform  in all directions.  It soon became apparent, how-
 ever, that even  with  all  the turbulence in the reactor, a float-sink  sep-
 aration was  taking  place  with  the heavier particles settling in a small
 dead  space (ca  Ig)  where  the stopcock is attached to the bottom of the
 reaction vessel.  This results  in poor or erratic pyrite analysis in  the
 first six hours  of  reaction when pyrite concentrations are high.  The
 pyrite  composition  of  the segregated material  was found to be over 10% w/w
 after 1  hour of  reaction  for coal  which initially had only 4.9% w/w pyritic
 sulfur.  Removing this material with 200 ml  leach solution, quickly adding
 it back  through the top of the reactor, and then taking a sample before
 any settling took place was not successful because the heavy particles
 rapidly, but unevenly, sand toward the bottom of the reaction vessel.
This  resulted in erratic pyritic sulfur values with differences of up to
 1%.   In some cases, the sampling of pyrite-rich areas resulted in apparent
pyritic sulfur gains of 1-3% after 1 hr of reaction.  The problem was fin-
ally  solved by using a "thief" technique in which an aluminum tube,
designed to take a 30-40 ml sample along the entire vertical axis of  the
reactor, was  rapidly inserted into the vessel  and then closed off when it
reached the bottom.  In order to guarantee that the high pyrite material
which collected in the bottom of the reactor was in suspension at the
time  the sample was taken, several  200 ml  aliquots were taken out of  the
bottom of the reactor and poured into the top just before the sample was
taken.  This  procedure was used on the final  five coals that were treated,
and good reactor-to-reactor precision and pyritic sulfur values consistent
with  ferrous  ion accumulation were obtained.
                                    24

-------
     It is also postulated that sampling problems would be substantially

reduced by removal of high density material by float-sink methods.   The
specifics of four different methods of reaction vessel  sampling,  as  well
as the coals sampled by each method, are briefly summarized below:

     Method A:  Lucas, Marion. Meigs, Mathies, Powhattan Coals.   A
     35 ml sample was taken from the bottom of the reactor after  first
     removing the coal plug in the valve with 200 ml of solution.
     Samples from all of the coals taken during the first 5-6 hrs
     were low in pyrite.  Precision for the Lucas, Marion and Mathies
     coals which had low initial pyrite (-1%) was good; precision for
     the Meigs and Powhattan coals was poor.  Only samples taken  after
     5-6 hours, when most of the pyrite is removed by chemical reaction,
     were considered reliable.

     Method B:  Muskingum, Isabella, Robinson Run, Delmont, Bird  No. 3,
     Star and Ken Coals.  In this procedure the coal plug was withdrawn
     with 200 ml of solution and added back to the reactor just before
     sampling.  This resulted in very poor precision between reactors
     and apparent increases in pyrite content during the first 3  hrs
     in several cases.  Samples taken during these runs were consid-
     ered reliable only after 8 hrs.  Reasonable results were obtained
     for the low ash Star and Ken coals.

     Method C:  Shoemaker and Williams Coals.  An aluminum tube with an
     open bottom that holds 30-40 ml within the vertical axis of the
     reaction vessel was rapidly inserted to the bottom of the reactor;
     then the bottom was closed off and the tube withdrawn.  This
     method gave good precision but may have given slightly low results,
     as with Method A.

     Method D:  Martinka, Kopperstone, Harris Nos. 1 and 2, North River,
     Homestead and all additional (No. 3) runs on the Powhattan No. 4,
     Williams and Lucas Mines.  Method C was modified by withdrawing
     the plug from the bottom of the reactor with 200 ml of solution
     and pouring it back into the top of the reactor.  This method
     gave good precision and the results were considered accurate.

4.3.1.3  Precision of Sulfur Analysis

     During the course of these studies, a substantial amount of sulfur

analyses data was collected which included 35 sets of sulfur forms  analyses

on untreated coals and an additional 34 sets on the treated coals.  It was

the practice during this research program to process multiple samples for

individual analysis rather than to perform a duplicate analysis on  a single

sample.  In this way, all sampling and handling errors were included in
each analysis, and the results would not appear artificially precise. The
                                    25

-------
standard deviation for each set of these  analyses was used  to calculate a
pooled standard deviation for each type of  analysis both  before and after
extraction.  The results of these  calculations  (tabulated in Table 6) show
that, in all cases, precision is excellent.   In addition, the precision of
the analysis on the treated coals  is only slightly less than that of the
untreated coals, indicating that the leaching and work-up procedures were
carried out in a very uniform way.

                                  Table 6
                    PRECISION OF SULFUR FORMS ANALYSIS
                 POOLED STANDARD DEVIATIONS,  %  W/W ABSOLUTE
Samples (Sn)
Initial (35)
Treated (34)
All (69)
SULFUR FORMS
Total
0.063
0.066
0.064
Pyrite
0.074
0.071
0.072
Sulfate
0.010
0.019
0.016
Organic
0.085
0.090
0.090
4.3.1.4  Atomic Absorption  Method  for Pyritic Sulfur Determination
     The analysis for pyritic sulfur normally requires approximately 1-5 g
of coal and substantial  labor for  the ASTM analysis'6'.  Because as many as
six to ten samples would be withdrawn from the chemical reactor containing
100 g coal during the course of a  run, it was apparent that the method of
analysis should be examined for modification that would allow a reduction
in both sample size and analysis time.  The following criteria were
considered:
     t  The methods of chemical extraction of sulfate and pyritic sulfur
        would not be changed because they have been accepted as effec-
        tive and because change would require a development effort out
        of scope of this contract.
     •  Only methods requiring 0.25-1.0 g of total sample would be
        considered.
     •  Since new methods which are characterized by  both speed and
        accuracy for determining  iron have  been developed in recent
        years,  these methods would  be examined for applicability.
                                    26

-------
     •  The iron analysis (pyritic sulfur)  should have  the  same
        accuracy and precision as the old method.
     The method of sulfur extraction used was identical  to  the ASTM proce-
dure^ ' in which both pyritic and sulfate sulfur determinations  are per-
formed on the same sample, with the exception that a 0.7-1.0 g sample is
used.  Iron oxide and ferrous sulfate are first extracted with refluxingSN
HC1 for 0.75 hr.  The filtered and washed residue is then extracted with
refluxing 5N HNO- for 0.5 hr to remove iron pyrite.  The extract solutions
are then brought up to volume for an iron analysis by the procedure
described below.  Sulfur is not determined directly because a small
amount of organic sulfur is usually extracted by the nitric acid.
     Atomic absorption spectrophotometry (AAS) was selected for  pyritic
iron determination for the following reasons:
     a)  The extraction of small amounts of organic material does not
         affect the determination.  Hence, several steps in the  ASTM
         procedure, which are designed to destroy organic material in
         order to prevent is reaction with the strong oxidizing  agent
         used in the subsequent titrimetric determination of iron,
         can be eliminated.
     b)  The atomic absorption method for determining iron  is normally
         free of interelement interferences.
     c)  Matrix effects can be eliminated by use of a dual  channel
         atomic absorption spectrometer, such as the Fisher Jarrell-
         Ash instrument.
     d)  Extracted color does not interfere with the determination
         as is the case for the ASTM procedure, which has a color-
         imetric endpoint.
     e)  The method is precise, accurate, fast,  and inexpensive.
     The results of analysis performed by the atomic absorption  and ASTM
methods are summarized in Table 7.  Note that in those  cases where multiple
analyses were performed, the precision of the AAS method is excellent.   In
fact, the precision obtained is that expected from a good  Eschka  (total)
                                     27

-------
                                                                Table 7
                                                      SULFUR FORMS ANALYSIS9'b'c
                                                ATOMIC ABSORPTION VS.  ASTM  PROCEDURES
Sample
Muskingum
Powhattan No. 4
Isabella
Mathies
Wi 1 1 i ams
Robinson Run
Shoemaker
Delmont
Marion
Lucas
Bird' No. 3
Marti nka
Meigs
Dean
Kopperston No. 2
Harris No. 1 and 2
North River
Homestead
Ken
Star
Eagle No. 2
Lower Kittanningf
Lucas
% w/w Pyritic Sulfur
AAS
0.22 ± .028
0.46 ± .064
0.06 ± .007
0.08 ± .000
0.28'± .049
0.08 ± .014
0.44 ± .148
0.22 ± .078
0.04 ± .007
0.22 ± .049
0.11 ± .014
0.12 ± .007
0.18 ± .035
0.20 ± .007
0.02 ± .000
0.02 ± .000
0.17 ± .028
0.22 ± .028
0.24 ± .050
0.04 ± .021
0.25 ± .004d
0.48 ± .038d
0.12 ± .007
ASTM
0.26 ± .007
0.43 ± .057
0.07 .007
0.02 .000
0.30 .035
0.08 .014
0.46 .120
0.20 .134
0.05 ± .014
0.20 ± .007
0.16 ± .035
0.12 ± .007
0.16 ± .035
0.16 ± .035
0.06 ± .035
0.07 ± .042
0.12 ± .021
0.22 t .092
0.30 ± .050
0.08 ± .028
0.19
0.33 ± .035
0.21 ± .034
Sample
Marion
Mathies
Meigs
Powhattan
Eagle No. 2
Jane
Fox
MeigsC
Powhattan No. 4
Muskingume
Mathiesc
Marion
Powhattan No. 4
Robinson Run
Lucas
Williams
Isabel la
Shoemaker
Meigs
Bird No. 3
Delmont
Eagle No. 2
Egypt Valley
% w/w Pyritic Sulfur
AAS
0.06 ± .021
0.02 ± .000
0.18 ± .035
0.46 ± .064
0.18
0.62
0.50
0.43
0.64
0.60
0,98 ± .007
0.34 ± .007
2.53 ± .000
2.72 ± .014
1.24 ± .007
1.94 ± .000
1.05 ± .042
2.18 ± .007
1.88 ± .191
2.64 ± .021
4.27 ± .014
2.66 ± .03dH
4.70 ± .004°
ASTM
0.05 ± .022
0.08 ± .000
0.16 ± .035

0.11
0.63
0.47
0.43
0.54
0.48
1.05 ± .065
0.90 ± .017
2.57 ± .060
2.89 ± .190
1.42 ± .082
2.23 ± .062
1.07 ± .070
2.19 ± .100
2.19 ± .030
2.87 ± .062
4.56 ± .044
2.67 ± .15d
5.07 ± .02°
I\J
co
                Unless otherwise noted,  all  analysis have been  performed on two samples of treated  coal.
                Values without standard  deviation are single  determinations.
               CA11  values greater than  1% are untreated coal.
                Average of 3 determinations.
               eAnalysis from trial runs.
                Sample from previous bench-scale program (Ref.  3).

-------
sulfur analysis rather than a sulfur forms analysis.   The results  are also
substantiated by the pyritic sulfur analysis of the final 23 hr samples
(see p. 32 for details of reaction conditions, including reaction  times)
which were determined both by the AAS method and by the standard ASTM
procedure performed by an outside commercial laboratory (CT&E). The
pooled standard deviation for all 20 sets of analyses was 0.032 for the
AAS method but was 0.060 for the ASTM method.  In addition, the number of
analyses which were rechecked and found to be wrong was much greater when
the ASTM procedure was used.  These "outliers" are not included in the
above calculations.  Thus, it appears that the AAS determination of iron
for the pyritic sulfur analysis gives a substantial improvement in preci-
sion over the ASTM procedure.
     In all cases, the agreement with the values determined by  the ASTM
method is excellent, although the AAS results tend to  be  slightly low in
certain cases.  Because treatment by the Meyers Process  tends  to  increase
the amount of color extractable  by  nitric acid, it is  possible  that these
small differences may partly be  due to difficulty  in determining  the end
point of the ASTM titration.  In general, however, the average values as
determined by both methods were  statistically interchangeable,  giving
further indication of the validity  of the accuracy of  the AAS  method.
     The AAS and ASTM determined values  of  the  final  pyritic sulfur content
of the treated coals are therefore  reported without  differentiation in
Appendix D and the two  sets  of duplicates were  used  to calculate  the
pyritic sulfur removal  for  the 20 additional coals treated in  this report.
4.3.2  Pyritic Sulfur Removal Results
     Table 8 summarizes  the  results of  the  pyritic sulfur removal experi-
ments.  The percentage  removal may  be calculated  by dividing the  differ-
ence between the  initial and final  weight percent pyritic sulfur  by the
initial weight percent  pyritic  sulfur.   However,  because of the ash  (both
pyritic and excess)  that is  removed,  the remaining pyritic sulfur in  the
treated coal  is  slightly concentrated,  and calculation of removal on  a
percent basis  results  in a  value lower  than is actually the case.  For
this reason,  a corrected value  was also calculated which compares the
                                     29

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                                                      Table 8

                                       SUMMARY OF PYRITIC SULFUR REMOVAL DATA3
u>
Q

Mine
Warwick

MusMngum
Egypt Valley No. 2)

'owhattan No. 4

sabella
Mathles
Wi 1 1 i ams

Huiiphrey No. 7
Robinson Run


Shoemaker
Delff'Ont
Marion
Jafie

Lucas

jird iJo. 3
Fox

Martinka
Meiggs

Seam
Sewickley

Meigs Creek No. 9
Pittsburgh No. 8

Pittsburgh Ho. 8

Pi ttsLiurgh
Pittsburgh
'Pittsburgh

Pittsburgh
Pittsburgh


Pittsburgh
Upper Freeport
Upper Freeport
Lower Freeport

lidOle Kittanning

4_rwpr Kittanni^o
Lower Ki ttarming

Lower Ki ttanning
Clarion lio. 1-A

Rank
hvAB

nvAb
nvAb

hvAb

hvAb
hvAb
twAb

hvAb
hvAb


hvftb
hvAb
nwb
hvAb

hvAb

1-,/h
fwAb

hvAb
hvBb

(tin
No.
1-3
4
-2
1-3
4
1-2
3
1-2
1-2
1-2
3
1-3
1-2

3
1-2
1-2
1-2
1-2
3
1-2
3
1-?
1-3
4
1-2
1-2

xn.
1me
23
13
23
13-226
13
23
23
23
23
23
23
23
23.5

23
23
23
23
11-236
23
23
23
?i
23
14
23
23

.each
hanqes
1
1
1
1
1
1
1
0
0
1

1
1

1
1
1
0
1
1
0
0
1
1
1
0
1

l*sbb
00
100
50
100
200
100
200
100
150
100
150
100
150

150
100
200
100
100
100
100
150
150
100
200
100
100
Wf mK pVfttTlC SULFUR I

.086

.65
.010
1.07
.025

2.75
-0.60

1.07
1.070
1.05
'.065
2.23
i . 062

1.59
1.114
2.89
'.190


2.19
^.100
4.56
t.044
0.90
'.017
1.44
±.098

i.087

?.82
-.062
3.09
'.017

1.42
'.010
2.19
'.030
LttlS. ft
FW
',043
0.06
0.24
.'.031
0.62
±.178 ,
0.38
0.44
-.051
0.04
0.04
'.0.00
0.05
-.035
0.29
-.086
0.10
0.14
'.055
0.08
•..012
0.08

0.46
f.lll
0.21
-.090
0.04
'.013
0.14
'..007
0.63
-.034
0.03
n. 13
'.034
0.37
-.163
n.26
0.12
-.006
0.17
'.029
/N
IM
+ .096
1.03
3.41
i.033
4.45
'.ISO
4.69
2.3!
^.079
2.71
1.03
1.070
1.00
±.074
1.94
'.072
2.13
1.45
».127
2.81
+ .190
2.11

1.73
'.149
4.35
'.100
0.86
'.021
1.30
i.098
0.81
>,.093
1.34
2.74
'.071
2.72
'.164
2.83
1.30
'.021
2.02
'.042
	 WRITE ftEMflWL 	 1

92
94
93
88
93
84
99
96
95
87
96
91
97
96

79
95
96
90
56
85
94
96
88
92
92
92
! "/M
92
95
94
89
93
85
99
96
95
88
96
91
97
96

80
96
96
91
60
35
94
96
89
93
92
93

4.0

0.9
3.5
...
1.9
—
0.3
3.3
1.7
—
3.5
0.5
	

5.1
2.0
1.5
0.8
—
2.6

1.2
5.3
—
0.4
1.3

-------
                                                          Table  8  (Cont'd)
Dean
No. 1
Kopperston No. 2
Harris No. 1&2
North River
Orient No. 6


Homestead
Eagle No. 2



Camp Nos. 142



Ken
Star
Wei don

Edna
Navajo

Belle Ayr
Colstrip
Lean
Mason
Campbell Creek
Eagle & No. 2 Gas
Corona
Herri n No. 6


Ho. 11
Illinois No. 5



No. 9 (W. Kentucky)



Ho. 9
No. 9
Des Moines No. 1

Wadge
Hos. 6,7,8

Roland-Smi th
Rosebud
hvAb
hvAb
hvAb
hvAb
hvAb
hvAb


hvBb
hvAb



hvBb



hvBb
hvBb
iivCb

hvCb
hvCb

subA
subA
1-2
1-3
1-2
1-2
1-2
1-3
4
5
1-2
1
2
3
4
1-3
4
5
6
1-2
1-2
1-3
4
1-3
1-3
4
1-3
1-3
23
23
13
23
23
23
23
13
23
13
14
14
23
13
23
23
13
23
23
23
13
23
23
6
6-10e
12-136
0
1
0
0
0
1
1
1
1
2
1
1
1
1
1
2
1
1
2
2
1
1
2
0
1
1-2
150
100
100
100
100
100
200
200
100
100
100
100
100
100
100
200
200
100
150
100
200
100
100
100
100
100
2.62
i.087
1.98
+ .062
0.47
±.026
0.49
+ .036
1.42
+ .026
1.30
+ .084


3.11
±.049
2.64
+ .154



2.80
±.120



2.85
+ .038
2.60
+ .100
5.2«
±.038

0.14
+ .015
0.28
, r\A A
± . U^H
0.22
+ .017
0.34
+ .015
0.17
+ .029
0.21
+ .045
0.04
±.029
0.03
+ .00
0.14
±.038
0.32
±.076
0.12
0.06
0.22
+ .056
0.36
0.11
0.33
0.19
0.62
+ .210
0.33
0.02
0.14
0.28
+ .021
0.24
±.029
0.47
±.099
0.15
0.06
±.020
0.04
±.040
0.03
0.03
+ .012
0.06
+ .006
2.45
±.092
1.77
' +.077
0.43
+ .039
0.46
+ .036
0.28
+ .046
0.98
±.113
1.18
1.24
2.89
±.074
2.28
2.53
2.31
2.45
2.18
+ .242
2.47
2.78
2.66
2.57
1.043
2.36
+ .104
4.77
+ .106
5.19
0.08
+ .025
0.24
+ .059
0.25
0.19
+ .021
0.28
+ .016
94
89
92
94
90
75
91 -
95
93
86
96
88
93
78
88
99
95
90
91
91
97
57
86
89
86
82
94
90
92
94
91
76
92
96
93
94
98
94
94
80
89
99
96
91
91
92
98
59
87
90
89
83
1.1
2.3
6.2
0.5
2.7
6.1


1.8




7.6



0.7
1.2
1.9

15
14

5.6
1.9
aWalker  mine omitted due to low  pyritic sulfur content  (0.07%).  b!00 mesh x  0  and 200 mesh x 0  coal  is symbolized as  100 and 200, respectively.
 This  value is calculated by  dividing the pyritic  sulfur loss in £ w/w by  the initial » w/w pyritic sulfur.   This value is calculated by  dividing
 the number of millimoles  of  sulfur loss by the  initial number of millimoles  of pyritic sulfur.  Indicates different  reaction times  with  no
 significant differences  in results.

-------
weight of the pyrite in the treated coal  to the weight of pyrite in  the
untreated coal.  The latter value, though harder to calculate because it
requires a material balance, is more nearly accurate than the former;
consequently, this value is used in the following discussions.
     The results of the pyritic sulfur removal  are very encouraging  in
that, with the exception of the very low pyrite western coals,  90-99% w/w
pyritic sulfur removal was achieved for all the coals treated.   The
western coals were reduced to a measured 0.09-0.06% w/w pyritic sulfur,
which were among the lowest values observed in  the program.  However, the
low  initial pyritic sulfur content of these coals (0.14-0.34% w/w) obscures
this fact in the percentage removal calculations, where removal of only
59-89% was obtained.
     The standard set of reaction conditions included a reaction time of
23 hours, one change of leach solution during the 4 to 6 hour time period,
and  the use of 100 mesh x 0 coal.  Although high removal was achieved with
the  low pyritic sulfur Belle Ayr, Colstrip, Navajo and Kopperston coals
using reaction times of only 6-14 hours, these conditions were  insufficient
for  high removal from many of the other coals.   Samples of the  other coals
were further ground to 150 or 200 mesh x 0 to expose more  finely divided
pyrite encapsulated in the coal and at the same time allow faster extrac-
tion, since the smaller size particles would thus  present  a  greater  sur-
face area for reaction.  The 200 mesh x 0  Camp Nos.  1  &  2  coal  was  run for
23 hours (Run No. 5), which resulted in 99% pyrite  removal compared  to
80-89% removal (Run Nos. 1-4) for  100 mesh x 0 coal. The remaining  pyrite
was  reduced from 0.62% to 0.02% w/w.  Since Run  No.  5  indicated a much
increased rate of removal,  an additional experiment (Run No. 6) was  per-
formed with a  total reaction time  of  13  hours.   This run resulted  in 96%
pyrite removal with a final  pyrite content of  0.14 w/w.   Another set of
experiments, using  200 mesh x  0  Orient  No. 6 (Run Nos. 4-5)  coal,  gave
much better removals  than  obtained with  100 mesh x 0 coal.  In the  23-hour
 run, the  removal  was  increased  from 76% to 92%,  and the final  pyrite con-
 tent was  reduced from 0.32% to 0.12% w/w.   Reducing the reaction time to
 13 hours  gave  an apparent increase in removal  to 96%, with a final   pyrite
 content of 0.06% w/w.  The small discrepancy is probably the result of
 accumulated experimental errors.

                                     32

-------
     Because of this observed increased removal during reduced reaction
time, a series of 13 and 14 hour runs using 200 mesh x 0 coal  was also
conducted with the Egypt Valle No. 21, Powhattan No. 4, Fox, Warwick, and
Wei don coals in order to check the generality of this phenomenon.  These
runs resulted in increased pyrite removals from 89 to 93% for the Egypt
Valley coal; 85 to 99% for the Powhattan No. 4 coal; 92 to 95% for the
Warwick coal; 92 to 98% for the Wei don coal; and 89 to 93% for the Fox
coal.  The corresponding final pyrite changes were 0.62% to 0.38%, 0.44%
to 0.04%, 0.09% to 0.06%, 0.47% to 0.15%, and 0.37% to 0.26%, respectively.
In a similar manner, grinding the Lucas coal to 150 mesh x 0 increased
removal by 9% to 94% and reduced the final pyritic sulfur content from
0.21% to 0.08%.  Thus, grinding the coals to 150 or 200 mesh x 0 allows
a much faster rate of reaction, and equal or increased pyrite removal  is
observed in all cases.
     Since kinetic data were being generated with the final 20 coals treated
in this survey, the reaction times were held at 23 hours except  in special
cases.  However, based on the final pyritic sulfur content obtained after
13 hrs in the trial runs, the coal was further ground to either  150 or
200 mesh x 0 in order to ensure greater than 90% pyritic sulfur  removal.
Using this technique, nine of the 20 coals were ground to 150 mesh x 0  and
six of the coals to 200 mesh x 0 in order to achieve this goal.   In addi-
tion, it was found on the basis of samples taken from the reactor after
13 hours, that pyritic sulfur removal was greater than 90% for eleven
coals, greater than 80% for seven coals, and indeterminate for two other
coals (due to poor samples).
     The data were examined by geographic region for the amount  of fine-
ness required in order to achieve greater than 90% pyrite removal.  It
was determined that, while it was not necessary to grind any Western coal
finer than the standard 100 mesh x 0 to obtain a low final pyritic content,
50-60% of the coals from both the Interior and Appalachian coal  basins
needed to be ground finer than the standard 100 mesh x 0.  Because of the
limited number of samples from the Interior Basin, no further correlation
could be made.  However,  for coals from the Appalachian Basin,  it was
found that 75% of the samples from both the Pittsburgh  (8 samples) and
Kittanning (4 samples) seams, 33% of the three Freeport samples, and 50%

                                     33

-------
of the two Sewickley samples needed size reduction.   Examination of the
Appalachian coal by stratigraphic groups showed  that 70% of the  10 samples
from the oldest Monongahela series including the Sewickley (Meigs Creek
No. 9) and Pittsburgh seams required further grinding.   In the Allegheny
Series including the Freeport and Kittanning seams,  60% of the 7 coals
needed further size reduction while only 20% (1  sample) of the remaining
6 different seam samples from the youngest Kanawha Group needed  to be
reduced further.  Thus, it appears that in order to  obtain 90-100% pyrite
removal, 50-60% of the coals from the Eastern part of the U.S. must be
ground finer than 100 mesh (149y).  For Appalachian  coals this requirement
increases for the older stratigraphic groups.  Furthermore, it was found
that additional comminution of the coal  increased the rate of pyrite
removal substantially, so that in all  but two cases  the target of 90%
removal was achieved in 13 hrs or less instead of 23 hours.
     The effect of coal particle size on the ultimate amount and rate of
pyrite removal  has emerged as a very important process variable.  Because
the present program was oriented toward complete pyrite removal, a detailed
study of particle size was not made.  Thus, while it appears that 50-60% of
the Eastern coals must be ground finer than 100 mesh (149y) for complete
removal (under the standard set of conditions utilized here), it is not
known whether or not >90% removal could be obtained  in certain cases  if
the coal  was reduced to only 80 mesh, 50 mesh or larger sizes.   In addi-
tion, the exact effect of coal fineness on the rate  of pyrite removal  has
not been established.  It is thus recommended that  further work  include
substantial studies on the effect of coal particle  size on the extent and
rate of pyrite removal.
     Although the precision of the results of this  survey has been excel-
lent, Run No. 2 on the Eagle No. 2 coal and Run No.  3 on the  Jane coal  are
exceptions; the former shows lower than expected final pyrite, and the
latter shows higher than expected final pyrite.  The data and circumstances
surrounding these experiments have been carefully examined and  checked and
no systematic reasons  can be found for these discrepancies.   The high
standard deviation for Runs  1 and 3 on the  Camp Nos. 1 and 2  coal  led to
the discovery that the temperature  controls  were maintaining  all  the leach
                                    34

-------
solutions 2-6 C below reflux; the spread in pyrite removals appears to
parallel these differences.  Run No. 4, carefully held at reflux, resulted
in much higher removal.  Although the results of the second set of 20 coals
are much more precise than the  initial set, a close examination of the
results listed in Appendices C  and D also shows that the spread between
triplicate pyritic sulfur values is often of the order of 0.1-0.2% w/w.
Thus, duplicate or triplicate runs or determinations are necessary in
order to obtain results that can be treated with a relatively high degree
of confidence.
4.3.3  Rate of Pyritic Sulfur Removal
     The rate of pyrite removal was also followed for the 20 coals sampled
for this part of the survey by  withdrawing slurry samples periodically
from the reactor.  As discussed in Section 4.3.1.2, some difficulty was
encountered in obtaining representative samples from the reactor.  The
principal problem was that the  boiling and stirred leach solution still
acted as a float-sink medium for the coals.  This was especially true for
the high ash ROM samples used in this survey.  Thus, 15 coals were leached
with varying degrees of success before a satisfactory method of sampling
was developed.  The metnod (Section 4.3.1.2 and Method D in Table 9) con-
sisted of using an aluminum tube that was rapidly inserted along the verti-
cal axis of the reactor and was closed off when it reached the bottom.
Assuming a uniform horizontal distribution, a representative slice was
therefore taken along the non-uniform vertical axis.  When interpreting
the data in Tables 9 and 10, the data obtained by Methods A, B and C from
samples taken during the first  six hours of leaching should be regarded
with some suspicion.
     The rate data are summarized in Table 9 in terms of % pyritic sulfur
removal, and in Table 10 in terms of pyritic sulfur content.  The data
indicate  that for all coals tested, the major portion of the pyrite is
removed in six to seven hours with the average removal being 85 ±6%
(median 86%).  After six to seven hours, pyrite removal slows down sub-
stantially; 90-95% removal is attained in 10-23 hours.  Although signifi-
cant reaction amounting to more than 10% occurred for the  Isabella, Bird
No. 3, and Meigs mines during the 12-23 hour interval, eleven mines had
                                     35

-------
                                                                                 Table
u>
                                         PYRITIC  SULFUR REMOVAL  AS  A  FUNCTION  OF TIME  IN PERCENT3 >b'c

Mine
lusklngum
Powhattan No. 4

Isabella
MatMes
Williams

Robinson Run
Shoemaker

Jelmont
larlon
Lucas

Bird No. 3
Fox
Marti nka
Meiggs
Dean
Kopperston No. 2
Harris Nos. 1&2
North River
Homestead
Ken
Star



Seam
Meigs Creek No. 9
Pittsburgh No. 8

Pittsburgh
Pittsburgh
Pittsburgh

Pittsburgh
Pittsburgh

Upper Freeport
Upper Freeport
Middle Kittanning '

Lower Kittanning
Lower Kittanning
Lower Kittanning
Clarion 4A
Dean
Campbell Creek
Eagle & No. 2 Gas
Corona
No. 11
No. 9
No. 9



Methodd
B
A
Df
B
A
C
Df
B
C
Df
B
A
A
Df
B
D
D
A
D
D
D
D
D
B&C
B



Mesh6
100
100
200
100
150
100
150
150
100
150
200
100
100
150
150
200
100
100
150
100
100
100
100
100
150


Initial %
Pyritic
Sulfur
3.65
2.75

1.07
1.05
2.23

2.89
2.19

4.56
0.90
1.42

2.87
3.09
1.42
2.19
2.62
0.47
0.49
1.42
3.11
2.85
2.66
Median
Range
Time, Hours
0.5
(51 )a
_c
58
--
(67)
(58)
55
—
54
51
--
(57)
(74)

--

42*
42*
12
66
51
58
4.9
--
43
53
12-74
1.0
(57)a
i.-
68
..

(72)
68
--
69
66
--


46
--
51
45*
58*
34
74
73
74
71
--

68
34-74
2.0


76



77


76





70






77
83
67
76
57-8
3.0
34
—

-
(68)
(87)
37
-
81

-
80
85
80
-
77
63
77*
59
87
84
77


88
78
34-8
5.0
73*b
--
82
54*
74
(92)
87
42*
85
87
-
88
85

63*

68
74
69

83
80
83
88
84
82
42-88
6.0
75*b

85



90
-


--


87
--
83



89


81
88
89
87
75-90
7.0







-
88

--



77



75

90

83
91
91
87
77-91
8.0
80


64
77
94


89


90
92
87
81
87
73


91

85



87
64-94
9.0

.-
74)














79









10.0

69



95
87










82






93
87
69-95
12 0

72



90


92







83



92
87


93
90
72-9
3 0
86

92
79
90

94
--

95
—
96
94
99
82
91

84
84
91


85


90
79-9
23 0
93
84
97
96
95
87
96
97
89
98
95
96
85
N.A.
95
N.A.
92
92
94

94
90
93
90
91
94
84-97
                     aValues in parenthesies are suspected of being high due to lack of ferrous ion accumulation and known deficiencies in the method of sampling.
                     bThe precision of the starred values is  poor.
                     CA dash indicates that the value was not included due  to extremely poor precision  or illogical analysis (e.g., gain).
                     dSee Section 4.3.1.2, p. 24 for exact details.   The slurry sample was withdrawn from the bottom of the reactor in Methods A & B.  In Methods C & D, a
                      thief technique was used.
                     eTop size of coal.
                     fResults are from a single repeat  experiment.

-------
                                                                Table  10
                  PYRITIC  SULFUR  REMOVAL  AS A FUNCTION  OF  TIME-% W/W PYRITIC  SULFUR*>b>C

Mine
Muskingum
Powhattan No. 4

Isabella
Mathies
Williams

Robinson Run
Shoemaker

Oelmont
Marion
Lucas

Bird No. 3
Fox
Martinka
Meiggs
Dean
Kopperston No. 2
Harris No. 1 & 2
North River
Homestead
Ken
Star

Seam
Meigs Creek No. 9
Pittsburgh No. 8

Pittsburgh
Pittsburgh
Pittsburgh

Pittsburgh
Pittsburgh

Upper Freeport
Upper Freeport
Middle Kittanning

Lower Kittanning
Lower Kittanning
Lower Kittanning
Clarion 4A
Dean
Campbell Creek
Eagle & No. 2 Gas
Corona
No. 11
No. 9
No. 9

Methodd
B
A
Df
B
A
C
Df
B
C
Df
B
A
A
Df
B
D
D
A
D
D
D
D
D
B&C
B

Mesh6
100
100
200
100
150
100
150
150
100
150
200
100
100
150
150
200
100
100
150
100
100
100
100
100
150
Initial %
Dv/yi fir
ryn 1 1 c
Sulfur
3.65
2.75

1.07
1.05
2.23

2.89
2.19

4.56
0.90
1.42

2.87
3.09
1.42
2.19
2.62
0.47
0.49
1.42
-rn —
2.85
2.60
Time, Hours
0.5
(1
(1
1

(0
(0
1

1
1

(0
(0



.80)d
.20)
.16
--
.41)
.93)
.00
—
.01
.08
—
.39)
.37)

--

0.83*
1
2
.26*
.30
0.16
0.24
0.60


1

.-
.47
1.0
(1.58)a
(1.10)
0.87
--

(0.63)
0.72
--
0.67
0.75



0.76
--
1.51
0.78*
0.92*
1.74
0.12
0.13
0.37

--
0.87
2.0


0.67



0.52


0.52





0.92






•OT

0.48
3.0
1.24
__b

--
(0.34)
(0.30)
0.30
--
0.42

--
0.18
0.21
0.29
--
0.70
0.53
0.72*
1.08
0.06
0.08
0.33


0.56
5.0
0.99*D
_b
0.50
0.49*
0.27
(0.18)
0.28
1.67*
0.33
0.29
—
0.11
0.21

1.07*

0.46
0.56
0.82

0.06
0.29

0.33
0.42
6.0
0.90*°

0.41



0.26
--

0.27
-


0.18
--
0.53



0.05



0.35
0.29
7.0







--
0.27

--



0.67



0.66

0.05


0.27
0.24
8.0
0.72


0.39
0.24
0.14


0.24


0.09
0.12
0.19
0.54
0.40
0.39


0.04

0.22



9.0

__b
0.72














0.47







10.0

0.86



0.12
0.28










0.40






0.18
12.0

0.78



0.22


0.18







0.24



0.04
0.18


0.18
13.0
0.52

0.23
0.23
0.10

0.14
—

0.12
—
0.04
0.08
0.02
0.51
0.28

0.34
0.42
0.04





23.0
0.24
0.44
0.08
0.04
0.05
0.29
0.10
0.08
0.46
0.04
0.21
0.04
0.21
N.A.
0.13
N.A.
0.12
0.17
0.17
N.A.
0.03
0.14

0.28
0.24
a) Values in  parenthesis are suspected of being  high due to lack of ferrous In accumulation and known deficiencies in the method of sampling.
b) The precision of the  starred values  is poor:
c) A dash indicates that the value was not included due to extremely poor precision or illogical  analysis  (e.g.,  gain).
d) See Section 4.3.1.2, page 24 for exact details.  The slurry sample was withdrawn from the bottom of the reactor in Methods A  & B.
   In Methods C and D, a thief  technique was used.
d) Top size of coal in mesh.
f) Results are from a single repeat experiment.

-------
insignificant removals of 5% or less and six of these mines  showed zero  or
negative removal  in at least one set of runs.   In respect to the remaining
mines, one was leached for only 13 hours, and no 13-hour samples were taken
in two cases.  Thus, it appears that a 23-hour reaction time should be
considered an upper limit for leaching and that, depending on the coal,
85-95% removal can be achieved in 6-13 hours.
     The data for leaching times below six hours is not nearly as easy to
interpret because of individual coal variations and because  the problems
with sampling are most evident when the pyrite content is high.  This can
readily be seen for the Muskingum, Powhattan No. 4, Mathies, Williams,
Shoemaker, Marion, Lucas and Fox coals, for which as long as 13 hours was
necessary for the ferrous ion build-up in solution to account for the
apparent pyrite decrease, assuming a sulfate/sulfur ratio of 1:5 (Fig-
ure 1).  These values, which are in parentheses in Tables 9  and 10, were
identified by checking the ratio of total ferrous ion present to the
amount of ferrous ion expected for the measured pyritic sulfur decrease
(see Section 4.3.4 and Table 13 for details).   A value less  than one indi-
cates that the measured pyritic sulfur removal obviously is  in error on
the low side.  However, a value greater than one may also be in error due
to a low measured pyritic sulfur coupled with a high degree  of ferric ion
reactivity with the coal.  Since this reactivity with the coal appears to
be nonlinear with time, there is no known adequate way to determine the
extent of this error.
     In spite of these problems, a substantial amount of information about
the pyrite removal in the early stages of the leaching has been obtained.
Median removal values have been determined from the data in  Table 9 and
were found to be 53% in 0.5 hours, 68% in 1.0 hour, 78% in 3.0 hours, and
87% in 6.0 hours.  The range of values was substantial:  12-74% at
0.5 hour, decreasing to 34-74% at 1.0 hour and closing further to 75-90%
in 6.0 hours.  Although the main reason for these variations may be due to
sampling problems, it is likely that they represent significant  individual
differences between coals.
     The median pyritic sulfur removal values in Table 9 are  plotted as a
function of time in Figure 3.  Note that, except for a small  amount of
                                    38

-------
                                  10   12   14
                                 Leach Time, Hrs.

              Figure 3.  Pyrite Removal as a Function of Time

scatter in the 4-8 hour region, a smooth line can be drawn through all  the
points.  This is an indication that, despite the wide range of removal
rates, the kinetic expression is the same order in pyrite, ferrous, and
ferric ion concentration in all cases.  The peculiar characteristics of
the coal, such as pore structure, size distribution of pyrite, etc., may
thus be primary factors affecting the rate constant, causing the removal
curve for a particular coal to fall either above or below that of Fig-
ure 3.  Since this is potentially a very significant area in terms of
predictions of the applicability of the Meyers Process, it is important
that these data be thoroughly examined at a future date for the purpose
of fitting a rate expression to these results.
4.3.4  Heat Content Changes and Ferric Ion Consumption
     The data in Table 11  presents  the results of ferric  sulfate extraction
of pyritic sulfur from coals in terms of changes in  heat  content of the
coals, and suggests a relationship  between this effect  and excess  ferric
                                    39

-------
                                   Table 11
    SUMMARY  OF HEAT CONTENT CHANGES  AND EXCESS FERRIC ION CONSUMPTION*



Coal Mine
Warwick
Muskingum
Egypt Valley No. 21
Powhattan No. 4
Isabella
Mathies
Williams
Humphrey No. 7
Robinson Run

Delmont
Marion
Jane
Lucas
Bird No. 3
Fox
Martinka
Meigs
Dean
No. 1
Kopperston No. 2
Harris NOS. 1 8 2

Orient No. 6
Homestead
Eagle No. 2
Camp Nos. 1 8 2
Ken
Star

Edna
Havajo6
Belle Ayr
Col strip



Seam
Sewickley
Meigs Creek No. 9
Pittsburgh No. 8
Pittsburgh No. 8
Pittsburgh
Pittsburgh
Pittsburgh
Pittsburgh
Pittsburgh
Pi ttsburqh
Upper Freeport
Upper Freeport
Lower Freeport
Middle Kittanning
Lower Kittanning
Lower Kittanning
Lower Kittanning
Clarion 4fl
Dean
Mason
Campbell Creek
Eagle 4 No. 2 Gas

Herrin No. 6
No. 11
Illinois No. 5
No. 9 (U. Kentucky
No. 9
No. 9

Wadge
Nos. 6, 7, 8
Roland-Smith
Rosebud

Dry Basis, btu/lb

Initial
8612
110H
10594
8603
8216
8154
13013
13631
12962
9495
11012
11046
11932
13451
10551
12973
7552
10246
12107
13054
10957
12414

11163
11935
10566
11103
12099
12308

12246
10050
12034
11591

Final
9365
11578
11506
9480
9312
9024
13587
13949
13764
10156
12108
11720
12392
13884
11500
13174
8138
11063
12663
13341
11340
12556

11034
12266
11401
11740
13689
12650

12201
10353
11520
11321
Chan
btu/lb
* 753
+ 564
+ 912
+ 877
+1096
+ 870
+ 574
+ 318
+ 802
+ 661
+1096
+ 674
+ 460
+ 433
< 949
+ 201
+ 586
+ 317
« 556
* 287
+ 383
+ 142

- 129
« 331
+ 835
+ 635
+ 590
+ 342

- 45
+ 303
- 514
- 270
£&
", w/w
+ 8.7
+ 5.1
+ 8.6
+10.2
+13.3
+10.7
+ 4.4
+ 2.3
+ 6.2
+ 7.0
+ 10.0
+ 6.1
+ 3.9
+ 3.2
+ 9.0
+ 1.5
* 7.8
+ 8.0
+ 4.6
+ 2.2
* 3.5
+ 1.1


» 2.8
« 7.9
t 5.7
+ 4.9
» 2.8

- 0.4
+ 3.0
- 4.3
- 2.3
Dry Mineral Matter
Free Basis,

Initial
153S1
14608
14851
14573
15197
14715
15309
15356
15321
15049
15842
15517
15682
14902
15835
15347
(16447)d
14503
15047
14997
(16300)
15585


14686
14994
14552
14614
14620

13602
13849
13111
13065

Final
15184
14106
14554
14607
15199
14925
15142
15137
15078
14841
15582
15533
15440
14930
15601
14775
15373
14250
14932
14743
15687
15302


14072
14579
14238
14209
14006
13467
13186
12908
11958
11993
btu/lb
Chana
btu/lb
- 197
- 502
- 297
+ 34
+ 2
+ 210
- 1F-7
- 219
- 243
- 208
- 260
+ 21
- 242
+ 28
- 234
- 572
-1074
- 253
- 115
- 254
- 613
- 283
-1063

- 614
- 415
- 314
- 405
- 614
- 864
- 416
- 638
-1153
-1072
5
% w/w
-1.3
-3.4
-2.0
+0.2
0
+1.4
-1.1
-1.4
-1.6
-1.4
-1.6
+0.1
-1.5
+0.2
-1.5
-3.7
(-6.5)
-1.7
-0.8
-1.7
(-3.8)
-1.8
(-6.4)

-4.2
-2.8
-2.2
-2.8
-4.2
-6.0
-3.1
-4.8
-3.8
-8.2

ntt
Excess
erric Ion
134
242
86
121
105
179
124
98
120
194
93
47
61
143
92
76
98
295
198
165
67
112
97

570
177
116
392
785
981
515
659
974
1520

mM/g
Excess
-erric Ion
1.36
2.42
0.88
1.21
1.05
1.79
1.24
1.00
1.20
1.94
0.93
0.47
0.62
1.43
0.92
0.72
0.98
2.95
1.98
1.69
0.67
1.12
0.97

5.70
1.83
1.20
3.92
7.85
11.31
5.33
6.66
12.04
19.09

++
Total Fe Expt.
Total Fe+* Calc!>

1.45
1.20
.33
1.79
3.04
1.40
1.43
.27
.71

.35
.79
.74
.21
0.89
1.48
1.92
1.51
1.90
1.97
2.53
1.48

2.24
1.47
.34
.96
3.09
1.56.
--c
--C
--C
-- c
a)  These values are the average of replicate 23-nour runs, except where noted.
b)  The calculated values are based on a sulfatetsulfur ratio of 1:5.
c)  These values have not been calculated because the low initial pyrite makes them uie
d)  Values in parenthesis are questionable due to high correction factors.
e)  Run No. 4.
ion consumption.   Because pyrite removal  is in  effect the  removal of low
btu "ash" (2995 btu/lb), its  removal  in most cases has more than compen-
sated  for any oxidation of  the coal matrix.  Thus, with  the exception of
the Western coals  and one Western  Interior Basin coal, heat content
increases of 1.1-13.3% were observed.   The Western coals,  with low
initial  pyrite  (0.14-0.34%  w/w) and a high order of reactivity with
ferric ion, had heat content changes  of +3.0 to -4.3%.
     Although dry  btu determinations  are useful for those  interested in
shipping and using coal, a  true picture of the  effect of ferric  ion
                                        40

-------
oxidation of the organic coal matrix and its relationship  to  excess  ferric
ion consumption can only be obtained by examining the dry  mineral matter
free heat contents.  These values (also listed in Table 11) show a heat
content loss of 3.1 to 8.8% for the Western coals, 2.0 to  6.0%  loss  for
the Eastern and Western Interior Basin coals, and a +1.4 to -3.7% change
for the Appalachian Basin coals.
     The heat content changes for the Martinka, Kopperston and  North River
mines are anomalous in that all three have abnormally high untreated dry-
mineral-matter-free heat contents of 16,300-16,600 btu/lb  which dropped
substantially after treatment to the area normal  for other coals, resulting
in calculated heat content losses of 600-1100 btu/lb.  The excess ferric
ion that reacted with 100 g of these coals was only 67-98  mM, which  is
entirely inconsistent with the 1000-1500 mM ferric ion required for  a
similar loss for the Belle Ayr and Col strip coals.  Because these coals
have an exceptionally high ash content, these errors may be due to  the
assumption used in the dry-mineral-matter-free calculation.   In addition,
sample calculations have shown that the dry ash free (daf) heat content
becomes very sensitive to small changes in analytical values  when  the ash
content of the coal is >40%.  For these reasons, these results are  con-
sidered suspect and are indicated by parentheses in Table 11.  These data
are therefore not included in the following calculations.
     The differences in dry-mineral-matter-free heat content loss  were
averaged for all three groups of coals (Table 12).  The Appalachian coals
averaged a loss of 172 ±185 btu/lb or 1 ±1.2%; the Eastern Interior Basin
coals, 592 ±237 btu/lb or 4 ±1.5%; and the Western coals, 896 ±331 btu/lb
or 7 ±2.6%.  These values were found to be mathematically significant by
the t test at the 99% level in all three cases, assuming that the method
    —                                                 (78)
of calculation did not introduce any systematic errorv  '  '.  Thus,  in view
of experimental uncertainties and calculation  assumptions, heat content
loss for the Appalachian coals must be considered  nil;  for the Interior
Basin coals, small; and for the Western coals, significant.
     The extent of reaction of the ferric  ion  with the  coal matrix  is
illustrated by examining excess ferric ion consumption.   Ferric ion
                                     41

-------
consumption was calculated by subtracting from the total ferrous ion pro-
duced the amount of ferrous ion that should have been produced by pyrite
removal, assuming the reaction chemistry of Figure 1 and dividing by the
actual amount of coal present (since the ferric ion can attack both the
organic and ash contents of the coal).  When the values are calculated on
a dry-mineral-matter-free basis, the scatter increases substantially.

                                  Table  12
           AVERAGE HEAT  CONTENT  LOSSES AND  FERRIC  ION CONSUMPTION
Coal Basin
Appalachian
Interior
Western
Dry Mineral Matter Free Heat Content, btu/lb
Average
Initial
15166+426
14658+208
13406+382

Average
Loss
172+185
592+232
896+331

Heat Content Loss
Per % Loss
172
148
128
1 49+22a
Excess Ferric Ion Consumption
Average
mM/g
1.3+0.6
5.2+3.5
10.8+6.3

mM/g Per %
Heat Content Loss
1.3
1.3
1.5
1.4+0.13
      aAveraqe value for all three coal basins
      These  calculations show  that  the coals  fall  into  three  distinct
 classes,  with  the Appalachian Coal  Basin  coal  consuming  0.47-2.95  mM/g
 excess  ferric  ion, the Interior Coal Basin coal  1.20-11.31 mM/g  excess
 ferric  ion  and the Western  coals 5.33-19.09  mM/g  excess  ferric  ion.   The
 corresponding  averages are  1.3, 5.2 and 10.8 mM/g,  respectively.   In  gen-
 eral, the results follow  the  degree of metamorphism of these coals.   The
 Western coals  have low rank and an  open pore structure,  which provides  an
 abundance of active sites for reaction.   The Eastern Interior Basin  coals
 have  a  higher  rank but still  have  an open pore structure that allows  sub-
 stantial  reaction, while  the  Appalachian  Basin coals,  though of  similar
 rank, have  the most closed  pore structure and  as  a  result show  very  little
 reaction  with  the ferric  ion.
      The  data  were examined further to establish  a  relationship  between
 heat  content loss and excess  ferric ion consumption.  These  results,  tabu-
 lated in  Table 12, indicate that 0.94 ±0.12  mM/g  ferric  ion  is  consumed
 for every 100  btu/lb loss in  heat  content.
 4.3.5   Ferric  Ion Consumption as a  Function  of Time
     The  rate  of ferric ion consumption was  also  followed as a  function of
 time, both  as  an independent  check  on the pyrite  removal values  and  to
                                    42

-------
determine whether the ferric ion reactivity with coal  is  linear  as  a
                                (1  23^
function of time.  Previous workv ' *  ' has shown that ferric  ion reacts
with pyrite according to Eq. 1:
   FeS2 + 4.6 Fe2 (S04)3 + 4.8 H20  -> 10.2 FeS04 + 4.8 H2$04 + 0.8S    (1)

to produce 10.2 mM ferrous ion per mM of pyrite (or 5.1 mM ferrous ion  per
mM pyritic sulfur) and a sul fate/sulfur ratio of 1.5.   Assuming this
stoichiometry, the mM/g coal excess ferric ion consumption (i.e., the
amount of reaction of ferric ion with the coal) can be calculated at  any
time, t , if the actual pyrite and ferrous ion concentrations are known
       A
at that time.  The calculation is shown in Eq. 2 and values of excess
ferric ion are listed as mM/g in Table 13.

              mM/g Coal Excess Ferric _ Total Reaction of
              Ion Consumption           Ferric Ion with Coal
           mM/g Coal Ferrous Ion - mM/g Coal Ferrous Ion Generated
                                   by Pyritic Sulfur Removal           (2)

These values can then be used to calculate the ratio shown  in  Eq. 3 and
tabulated in Column 5 of Table 13.

    Ratio = Actual Ferrous  Ion     / Ferrous  Ion  Generated  by  Pyrite
            Present in mM/g Coal /  Removal  in mM/g Coal               (3)

The value for Eq. 2 must be positive, and the  value for  Eq.  3  must be  1.0
or greater by definition.   It should be  noted,  however,  from the data
shown in Table 13, that several negative  values for Eq.  2 were obtained,
indicating that the input data for  either ferrous ion  or pyrite concentra-
tion were incorrect.  As a  result of this finding, both  the means of
sampling and the analysis of both leach  solution  and coal were examined
for possible error.  This examination  indicated that sampling  error was
clearly the cause, since all other  methods were standard and tested  proce-
dures.  This problem and its solution  is  documented in Sections 4.3.1.2
and 4.3.3 and will not be further discussed  in this section.
                                     43

-------
                                      Table 13
                  FERRIC  ION CONSUMPTION  AS A  FUNCTION OF TIME*


Mine
Muskingum
Powhattan
No. 4


Isabella

Mathies

Williams



Robinson Run

Shoemaker



Delmont

Marion

Lucas



Bird No. 3

OX

Martinka

Meigs

Dean

KODperston
Ho. 2
Harris No.
1 I 2
North River

Hoaestead

Cen

Star



Seam

Pittsburgh No. 8



Pittsburgh

Pittsburgh

Pittsburgh



Pittsburgh

Pittsburgh



Upper Freeport

Upper Freeport

Middle Kittanning



Lower Kittanning

Lower Kittanning

Lower Kittanning

"larion 4A

Dean

Campbell Creek

Eagle « No. 2 Gas
Corona

No. 11

No. 9

No. 9


Sampl ing
Method

A

D

B

A

c

0

B

C

0

B

A

A

D

B

D

D

A

D

D

D
0

0

BtC

B



Meshc

100

200

100

150

100

150

150

100

150

200

100

100

150

150

200

100

100

150

100

100
100

100

100

150

Excess
Ferric
lond.e
mM/g
Ratio
mM/g
Ratio
mM/g
Ratio
mM/g
Ratio
mM/g
Ratio
mM/g
Ratio
mM/g
Ratio
mM/g
Ratio
mM/g
Ratio
mM/g
Ratio
mM/g
Ratio
mM/g
Ratio
mM/g
Ratio
mM/g
Ratio
•H/9
Ratio
mM/g
Ratio
mM/g
Ratio
mM/g
Ratio
mM/g
Ratio
mM/g
Ratio
mM/g
Ratio
T*/(I
Ratio
mM/g
Ratio
mM/g
Ratio
mM/g
Ratio
Time, Hours

0.5
0.81
-0.94
0.62
0.56
-1.22
1.58
-1.32
-0.14
0.86
-0.77
0.63
0.88
1.45
2.93
-2.61
-0.08
0.96
0.87
1.49
3.74
-1.04
-0.13
0.84
-0.76
0.55
--
--
2.15
-3.67
_„
--
0.24
1.26
0.43
1.29
1.71
4.36
0.25
1.50
0.51
2.33
0.07
1.05
0.59
1.24


1.51
1.!I4
1.0
0.96
-0.68
0.74
1.03
1.34
1.44
-4.02
0.45
1.40
-0.75
0.70
1.25
1.52
5.97
-0.93
-0.33
0.86
0.93
1.41
5.52
-1.04
0.11
1.09
-0.30
0.84
1.35
2.29
2.61
-8.11
-1.84
0.49
0.65
1.64
0.44
1.22
1.51
2.08
0.50
1.90
0.52
1.90
0.12
1.0'
0.35
1.10
_.
--
1.30
1.47
2.0



1.33
1.40






1.69
1.62




1.00
1.38










-2.02
0.56











1.00
1.26




3.0
1.14
-0.25
0.91


0.95
2.57
0.58
1.47
-0.49
0.84


3.21
5.12
0.09
1.03


3.13
3.94
0.12
1.10
0.04
1.02
2.35
2.31
2.78
6.83
-2.04
0.58
0.80
1.57
1.04
1.45
1.45
1.59
0.77
2. IB
0.76
2.16
0.56
1.32


0.56
1.15
2.22
1.68
5.0
1.09
•0.05
0.98
2.56
1.71
0.82
1.89
0.75
1.58
-0.20
0.94
2.36
1.76
2.20
2.13
0.34
1.12
1.77
1.59
2.90
2.50
0.22
1.17
0.23
1.11


0.86
1.30


1.07
1.70
1.30
1.50
1.64
1.57
0.94
2.41
0.92
2.34
O.S2
1.46
1.91
1.46
0.88
1.2?
2.81
1.81
6.0
1.29












2.14
1.99




•0.36
0.94




2.91
2.48
1.72
1.82
1.96
0.62











3.39
1.84
1.89
1.47
3.70
2.01
7.0
1.32












1.15
1.33
0.63
1.21


1.40
1.33






0.56
1.16






2.10
1.68


1.07
2.53

3.85
1.94
2.20
1.54
4.17
2.11
8.0





0.83
1.77


-0.05
0.98




1.07
1.34








3.57
2.83
0.47
1.13
-2.01
0.62
1.28
1.78




0.88
2.28
0.88
1.46







9.0

-0.32
0.92






























1.89
1.69













10.0

0.88
1.29






0.15
1.04





































12.0









0.75
1.24




1.32
1.41














1.20
1 .04
2.17
1.76




1.16
2.63
0.89
1.45




5.25
2.36
13.0
1.94
1.39
1.17
1.37




0.82
1.54




1.21
1.31




0.67
1 .11
0.29
1.21
0.59
1.28
3.69
2.66
0.72
1.19
-2.19
0.61
0.98
1.48
2.58
1.88
1.72
1.49
0.67
1 .97



5.00
2.20


6.12
2.5?
23.0
2.42
1.45
1.21
1.33
3.65
1.84
1.05
1.79
1.79
3.04
1.24
1.40
3.11
1.92
1.20
1.27
1.94
1.71
2.60
1.76
0.93
1.16
0.47
1.35
1.43
1.74
..
--
0.92
1.21




2.95
1.92
1.98
1.51
--
--
1.12
2.53
0.97
1.48
5.32
2.15
3.92
1 .96
7.85
3.09
aThese values correlate with those in 7flh1e<> 9 .ind IT.
^Sec Section 4.3.1.2, p. 24 for exact details.  The slurry sa^-ole v.is w
 a "thief" technique was used.
 Top size of coal
^irtl/g * calculated irnllimolcs of ferric ion tnrtt re
-------
to conclusively show whether or not the effect is linear.   Since the rate
                                           (1  3)
of removal of pyriteisa nonlinear reactionv    ', the variation of the ratio
in Eq. 3 was closely examined.  A constant ratio would indicate coal  reac-
tivity paralleling the rate of pyrite removal.  The results indicate that
for the Powhattan No. 4, Williams, and Homestead mines the ratio increased;
for the Shoemaker, Lucas, Harris No. 1 & 2 and North River mines, there
was a slight increase; the Martinka and Kopperston mines showed small
changes and the Dean mine showed a drop.  Thus, it appears that reactivity
with the coal matrix depends to a large extent on the nature of the coal
and that this phenomenon should be examined in detail in the future,
4.3.6  Removal of Residual Sulfate
     The data presented in Table 14 indicate that substantial sulfate is
retained on some coals when a minimal coal wash procedure is used after
extraction of pyritic sulfur.  The wash procedure consists of three 500 ml
hot water rinses of the coal on the filter funnel after filtration of the
reaction mixture.  This procedure, which was used on many trial runs and
the final triplicate runs for Camp Nos. 1 & 2 and Orient No. 6 coals,
resulted in sulfate values (sulfur as sulfate, but referred to only as
sulfate in the following discussion) ranging from a very acceptable
0.06-0.10% (Jane, Humphrey No. 7 and Col strip) to a very high 0.45-0.85%
(Mathies, Orient No. 6, Eagle No. 2, Belle Ayr, and Edna) with the majority
of coals falling in the range of 0.2-0.4%  (see Table 14).
     It is currently believed that sulfate retained on the treated coals
can be reduced or eliminated by one or more of the following methods:
(a) control of acidity and iron concentration or form during extraction,
(b) selection of optimum filtration temperature,  (c) equilibration of the
leach solution with the coal as in the thickener section of a process plant,
or (d) selection of the appropriate washing parameters.  Because detailed
evaluation of these processing techniques was not practical during this
program, only those approaches involving washing techniques were investi-
gated.  Several of these methods have been evaluated under a separate EPA
program for bench-scale experimentation (Contract No. 68-02-1336, Refer-
ence 3) and have been found to be effective.
                                    45

-------
                                      Table 14
                       SULFATE CONTENT  OF TREATED COALS*
                                       (%  w/w)
Mine
Warwick
Muskingum
Egypt Valley No. 2
Powhattan No. 4
Isabella
Mathies
Wi 1 11 ams
Humphrey No. 7
Robinson Run
Shoemaker
Delmont
Marion
Jane
Lucas
Bird No. 3
Fox
Martinka
Meigs
Dean
No. 1
Kopperston No. 2
Harris Nos. 1&2
North River
Orient No. 6
Homestead
Eagle No. 2
Camp Nos. 1&2
Ken
Star
Wei don
Edna
Navajo
Belle Ayr
Col strip
Seam
Sewickley
Meigs Creek No. 9
Pittsburgh No. 8
Pittsburgh No. 8
Pittsburgh
Pittsburgh
Pittsburgh
Pittsburgh
Pittsburgh
Pittsburgh
Upper Freeport
Upper Freeport
Lower Freeport
Middle Kittanning
Lower Kittanning
Lower Kittanning
Lower Kittanning
Clarion 4A
Dean
Mason
Campbell Creek
Eagle & No. 2 Gas
Corona
Herri n No. 6
No. 11
Illinois No. 5
No. 9 (W. Kentucky)
No. 9
No. 9
Des Moines No. 1
Madge
Nos. 6,7,8
Roland-Smith
Rosebud
Mesh
100
150
100
100
100
150
100
100
150
100
200
100
100
100
150
100
100
100
150
100
100
TOO
100
200
100
100
100
100
150
100
100
100
100
100
% W/W SULFATE
nitial
0.01
0.06
0.14
0.19
0.04
0.04
0.04
0.01
0.06
0.05
0.08
0.02
0.00
0.05
0.05
0.05
0.07
0.06
0.15
0.08
0.03
0.03
0.07
0.01
0.10
0.04
0.06
0.26
0.24
0.15
0.00
0.03
0.00
0.00
Regulara'b
12-14 Mrs.
...
0.11

0.08
0.04

0.02

0.06
0.04
0.05



0.05

0.08
0.13


0.07

0.08
0.17

0.18


0.12

0.15
0.12e
0.14
0.06
Minimala'b
12-14 Hrs.
0.35

0.25


0.65

0.10



0.40
0.06
0.23

0.31


0.22
0.26

0.30

0.45d
0.40
0.85d
0.42d
0.38
0.42
0.31
0.68
0.54
0.64
0.06
Regular3'0
21-23 Hrs.
0.14
0.17
0.11
0.12
0.01
0.10
0.06
0.10
0.00
0.08
0.06
0.06
0.06
0.13
0.11
0.09
0.08
0.14
0.16
0.09
0.08
0.06
0.09
0.22
0.30
0.23
0.28
0.26
0.34
0.18
0.49

0.85

aSee text for explanation of procedure.
 Most of the data in  this column is  derived from single analysis  trial runs.
cThe data in this column are derived from the average of the analysis of two
      or three runs.
d23-hr. run.
e6-hr. run.
                                         46

-------
     Table 15 summarizes sulfate extraction experiments performed  on  the
treated Camp Nos. 1 and 2 coal.  Note that both methanol  and aqueous
methanol are much less effective than water in reducing the sulfate con-
tent of the coal, but that the addition of 1% v/v sulfuric acid to aqueous
methanol reduces the sulfate to 0.24% w/w.  In addition,  basic solutions
such as 5% w/v sodium carbonate and 10% v/v concentrated ammonium  hydroxide
in aqueous methanol, and chelating agents such as 3% w/w ethylenediamine
tetraacetic acid and 10% w/w tetraethylene tetraamine, are apparently
slightly more effective than water in reducing the sulfate level.
     Table 16 summarizes a second set of sulfate extraction experiments
performed on treated Orient No. 6 coal.  With this coal, an additional  wash
with either water, 0.1-3N sulfuric acid, or IN oxalic acid for one hour at
elevated temperature was effective in reducing the sulfate level from 0.62
to 0.25% w/w or  less.  Washing with  IN sulfuric acid at 30°C  (Expt.  6)  was

                                 Table 15
                    SPECIAL SULFATE  REMOVAL EXPERIMENTS
                         CAMP  NOS. 1 AND  2 COALa.b
Experiment
1
2
3
4
5
6
7
8
Reagent
H20
CH3OH
aq.CH3OHc
1% H2S04 in aq. CH3OHC
5% Na2C03 in aq.CH3OHc
10% NH4OH in aq.CH3OHc
3% EDTA in aq. CH3OHC
10% Tetraethylene
tetraamine in aq. CH3OH
Temp.,°C
Reflux
Ref 1 ux
Ref 1 ux
Reflux
Reflux
Reflux
Reflux
Reflux
Final % S04> w/w
0.19
0.33
0.49
0.24
0.13
0.20
0.13
0.11
 alnitia1  sulfate retention 0.42% w/w, the ratio of coal to extraction
  solution was 1:60 w/v
 ^Extraction time of four hours followed by thorough water wash
 cMethanol:water ratio of 7.3
                                     47

-------
                                 Table 16
         SPECIAL SULFATE REMOVAL EXPERIMENTS, ORIENT NO.  6 COALa'b
Experiment
1
2

3
4
5

6
7
Reagent
H20
0.1N H0SQ.
2 4
0.5N H2S04
l.ON H2S04
3. ON H9SOA
2 4
l.ON H2S04
IN Oxalic Acid
Temp . , °C
^90
^80

^80
^80
*v80

^30
-V60
Final % S04> w/w
0.25
0.21

0.23
0.19
0.23

0.36
0.16
 Initial sulfate retention 0.62% w/w, the ratio of coal  to extraction solu-
 tion was 1:20 w/v
 Extraction time of one hour followed by thorough hot water wash

not as effective, giving a final sulfate value of 0.36% w/w and indicating
that elevated temperature is necessary for more effective sulfate removal.
However, since the results of all 7 experiments are from single trials and
since the values, with the exception of Experiment 6, are grouped so
closely, the remaining six methods (Methods 1, 2, 3, 4, 5 and 7) in Table 16
can be considered equally effective at this point.
     Based on the above experimentation, water washing as well as washing
with dilute sulfuric acid is capable of removing residual sulfate.  Dilute
sulfuric acid should be advantageous in those cases where basic iron sul-
fates are present.  Basic solutions or chelating agents, though effective,
would introduce unnecessary process expense and should not be considered if
the above methods are effective.  Therefore, the following standard proce-
dure was adopted for the survey studies in order to ensure, without opti-
mization, a low level of sulfate in the treated coals.
     The extracted coal is slurried with 2 Jl of IN sulfuric acid at
     MJOOC for 2 hours, filtered and stirred with another 2 I IN sul-
     furic acid at ^800C for an additional two hours.  After
                                    48

-------
     filtration, this procedure is repeated with 2 £ water at ^80 C.
     If scheduling does not permit the coal to be extracted with
     toluene immediately, stirring is continued at ^50°C for an
     extended period until filtration and extraction can be
     performed.
     The results listed in Table  14 are  summarized  in  Table  17  and show
that the final  sulfate content can be reduced  to 0.06-0.17%  w/w for the
Appalachian Basin  coals,  0.17-0.35% w/w  for  the Eastern and  Western Interior
Basin coals, and 0.06-0.85% w/w for the  Western coals  using  this method.
The median final sulfate  values for 23 hr  runs involving the Appalachian
and Interior Basin coals  were 0.09% and  0.28%, respectively, indicating
that sulfate retention  is much more pronounced for the Interior Basin coals.
Data for 12-14 hr  reaction times  indicate  that reaction time did not sig-
nificantly affect  the final  median sulfate content of the Appalachian
coals,  while the median for the  Interior Basin coals is reduced 0.11% to
0.17%.  With the Western coals,  reaction times of 6-14 hrs were necessary
in order to prevent excessive sulfate retention.   Thus, given a standard
set of  working conditions, it can be concluded that sulfate retention
depends both on the coal basin in which it is mined and to a certain extent
on the  coal  leaching time.

                                  Table  17
                   SUMMARY OF TREATED COAL SULFATE  CONTENT
                                   (% w/w)

Appalachian
a) 23 hrs.
b) 12-14 hrs.
Interior
a) 23 hrs.
b) 12-14 hrs.
Western
a) 23 hrs.
b) 6-14 hrs.

Initial"

0.05

0.09

0.00

Treated

0.09
0.06

0.28
0.17°

d
0.13



0.06

0.12

0.01
Treated

0.09
0.07

0.26r
0.16C

>0.50d
0.12
Low
initial

0.00

0.01

0.00
Treated

0.00
0.02

0.18r
0.17C

0.49
0.06
Hiah
initial

0.19

0.26

0.03
Treated

0.17
0.13

0.34.
0.18

0.85
0.15
^MBHM^^^H
    aROM unleached coal.
    treated coal washed by procedure on page 48to remove sulfate.
    cInsufficient data-two runs only..
          runs only.
                                       49

-------
      In addition to the above conclusions, it should also be kept in mind
 that, as  indicated in Table 14, the amount of sulfate retained appears to
 depend somewhat on the individual characteristics of the coal.  Also, the
 washing procedure used here, while conforming to the general constraints
 of  the Meyers Process, has not been optimized.  In particular, the use of
 a continuous countercurrent wash or multiple washes may be as effective as
 the prolonged washes used above.  Moreover, a sulfuric acid wash may not
 be  necessary.  Thus, for a complete understanding of the problem, several
 coals should be further investigated in detail in order to determine the
 minimum conditions necessary for sulfate removal.
 4.3.7  Summary of Ash Changes
     Table 18 summarizes the ash changes which occurred upon extraction of
 the coals with ferric sulfate.  The expected ash change or loss can be
 computed from the relative molecular weights and the assumptions that all
 the pyritic sulfur FeS,,, is converted to iron oxide (Fe?0 ) in the ashing
              o
 process at 800 C:

                FeS2 + 2.75 02	 0.5 Fe203 + 2 S02
                M.W. 119.85               M.W. 159.70
Thus,  64.00 g of sulfur from FeSp is converted to 159.70 x 0.5 or 79.85 g
of ferric  oxide during the ashing process, which results in 1.25% ash
 (79.85/64.00) production for every 1.00% pyritic sulfur present.  The
calculated ash loss can then be computed by multiplying the absolute per-
cent pyritic sulfur removal by 1.25.  In all cases, more ash was removed
than can be accounted for by pyrite removal alone.  In general, excess
removal  was greatest for the Western coals which averaged 3.9% excess
removal,  while coals from the Appalachian and Interior Coal Basins had
similar excess removals, averaging 2.4 and 2.6%, respectively.
     The various coal  mines were also examined for correlations by seams
and ash content (Table 19).  In the Appalachian region, there were no
significant differences between the coal seams.  In the Interior coal
basins, differences occurred between seams; however, these results are not
considered significant because of the small number of mines considered.
When the coals are examined by ash content, it is clear that excess removal

                                    50

-------
                                    Table 18

                          SUMMARY  OF ASH CHANGES
                                   (% W/Wa)
Mine
Warwick
luskingum
igypt Valley
No. 21
Powhattan No. 4
Isabella
Mathies
Wi lliams
Humphrey No. 7
Robinson Run
Shoemaker
Delmont
Marion
Jane
Lucas
Bird No. 3
Fox
Marti nka
Meigs
Dean
No. 1
Kopperston No. 2
Harris Nos. 1&2
North River
Orient No. 6
Homestead
Eagle No. 2
Camp Nos. 1&2
Ken
Star
Wei don
Edna
Navajo
Belle Ayr
Colstrip
Seam
Sewickley
Meigs Creek No. 9

Pittsburgh No. 8
Pittsburgh No. 8
Pittsburgh
Pittsburgh
Pittsburgh
Pittsburgh
Pittsburgh
Pittsburgh
Upper Freeport
Upper Freeport
Lower Freeport
Middle Kittanning
Lower Kittanning
Lower Kittanning
Lower Kittanning
Clarion 4A
Dean
Mason
Campbell Creek
Eagle & No. 2 Gas
Corona
Herri n No. 6
No. 11
Illinois No. 5
No. 9 (W. Kentucky)
No. 9
No. 9
Des Moines No. 1
Wadge
Nos. 6,7,8
Roland-Smith
Rosebud
Initial
40.47
21.68

25.29
37.17
42.22
41.01
13.18
9.88
13.36
33.48
27.18
26.40
21.75
8.68
30.23
13.55
49.25
26.53
17.28
11.39
30.15
18.63
49.28
22.51
16.56
26.53
21.13
15.08
13.90
15.74
9.13
25.29
7.55
10.38
xtracted
35.32
16.05

18.86
32.13
35.72
36.43
9.16
6.97
7.63
28.87
20.44
22.61
17.99
6.32
24.17
9.72
43.46
20.38
13.66
8.50
25.53
16.46
42.84
18.85
11.50
19.80
15.77
9.44
8.58
6.43
6.77
20.53
3.37
5.17
C
Change
-5.15
-5.63

-6.43
-5.04
-6.50
-4.58
-4.02
-2.91
-5.73
-4.61
-6.74
-3.79
-3.76
-2.31
-6.06
-3.83
-5.79
-6.15
. -3.62
-2.89
-4.62
-2.17
-6.44
-3.66
-5.06
-6.73
-5.36
-5.64
-5.32
-9.31
-2.36
-4.76
-4.18
-5.21
al culated
Change"
-1.25
-4.26

-5.56
-2.89
-1.29
-1.25
-2.43
-1.81
-2.43
-2.16
-5.44
-1.08
-1.63
-1.51
-3.43
-3.40
-1.63
-2.53
-3.06
-2.21
-0.54
-0.58
-1.60
-1.23
-3.61
-2.96
-2.73
-3.21
-2.95
-5.96
-0.10
-0.30
-0.24
-0.35
ixcess
-3.90
-1.37

-0.87
-2.15
-5.21
-3.33
-1.59
-1.10
-3.31
-2.45
-1.30
-2.72
-2.13
-0.80
-2.63
-0.43
-4.17
-3.63
-0.56
-0.68
-4.08
-1.60
-4.84
-2.43
-1.45
-3.77
-2.63
-2.43
-2.37
-3.35
-2.26
-4.46
-3.94
-4.86
aAll  values in the  Table are in % W/W and are an average of two or more values based on
 Runs 1 and 2 in Appendix D and Runs 1,  2 and 3 in Reference 2.

bBased on the removal of pyrite, FeS2-
                                         51

-------
                                  Table 19
                         AVERAGE EXCESS ASH REMOVALS
                                   (% W/W)
Region

r d
Appalachian (23)c - 2.4


Eastern &
Western
Interior (7) - 2.6
Western (4) - 3.9


Seam3
Sewickley (2)c
Pittsburgh (7)
Freeport (3)
Kittanning (5)
Others (5)
Herrin No. 6 (2)
Illinois No. 5 (4)
Des Mgines No. 1 (1)
2.6d
2.7
2.4
2.3
2.4
1.9
2.8
3.3

Ash Content
Low (7)c

Medium (8)
High (8)

Low (4)
Medium (3)
High (0)
Low (3)
Medium (1)
High (0)
1.2d

2.1
3.7

2.4
2.9
—
3.7
4.5
—
  aSeam correlations:  1) Sewickley = Meigs Creek No. 9; 2) Herrin No. 6 = No. 11; 3) Illinois
                 No. 5 = No. 9.
  bLow Ash, 0-15%; Medium Ash, 15-25%; High Ash, >25':.
  cNumber of mines in sample.
  Average ash loss in weight %.
increases with  increasing ash content.  This is most apparent with the
Appalachian coals, where high ash coals (>25% w/w) have more  than three
times the excess  removal of low ash coals (0-15% w/w).
     Since the  aqueous  extraction solution is both acidic and oxidizing,
inorganic materials  in  the ash could be brought into solution by either
an acidic or oxidizing  attack.  However, the most likely mechanism of sol-
ution probably  is dissolution of basic inorganic compounds  by the sulfuric
acid that is present in solution (Figure 1).  Since acid soluble compounds
of sodium, potassium, magnesium and iron, such as oxides and  carbonates,
can be major constituents of coal ash, they could easily account for the
excess ash removal.   However, since research has thus  far not accurately
resolved these  questions, additional experimentation should be performed
in order to establish purification requirements for recycled  ferric sul-
fate streams.   In addition, the use of "cleaned" coal  which normally has
40-70% less ash than ROM coal would substantially reduce any purification
requirements.   Operation of a continuous large-scale (pilot)  facility may
be required to  completely clarify potential problems in this  area.
                                     52

-------
4.3.8  Organic Sulfur Changes
     After several coals had been extracted, the results seemed  to  indicate
that the treated coal apparently had a higher organic sulfur  content  than
the starting coal.  Although organic sulfur increases of 0.01-0.14% w/w  were
attributable to ash removal, these did not account for all  of the apparent
increases.  However, the organic sulfur value is the least  accurate of all
sulfur analyses because it is not determined directly, but  by subtracting the
amount of pyritic and sulfate sulfur from the total sulfur.  For this reason,
the organic sulfur value contains resultant errors from all three analyses.
Thus, according to ASTM Standards^  , duplicate organic sulfur values with
spreads of up to 0.4-0.6% w/w can be considered acceptable  for analyses  done
by different operators in different laboratories.  The problem is made  even
more complicated due to the  possibility that treating the coal with ferric
sulfate solution can introduce a systematic error in the results.   Therefore,
a thorough statistical analysis was made in order to assess the validity of
the indicated results.
     All the data were tested for significance by applying the t test,  in
which the value of £ was calculated according to the equation:

                             t  =  (B  - A)  N/h
                                      °d
where
     A   =  average starting organic  sulfur,
     F   =  the average final organic sulfur,
     n   =  the number of values  in each  set, and
     a.  =  the standard deviation of the  difference  B  - A.
      d

The value of t is then used  to determine  the  level  of  significance by con-
sulting a standard table of  values used for  the  t  distribution^  .
     These data, which are  summarized in  Tables  20 and  21, show that,
although no increases are found for Western  coals,  significant  average
increases of 0.23 and 0.31%  w/w are found  for the  Appalachian and  Interior
coals, respectively.  Differences between  various  seams in each region  and
between these regions themselves were tested  and not  found to be signifi-
cant.  The chances that the  organic sulfur increases  for coals  in  these
regions are real were found  to be significant at the  99% confidence  level.
                                    53

-------
                                                       Table 20
                                                 ORGANIC SULFUR DATA
tn
Mine
Warwick
Huskingun-
tgypt Valley no. 21
(•owhattan i-lo. 4
Isabel 1*
Mathles
Williams
Humpnrey No. 7
Robinson Run
Shoemaker
Delmont
Marlon
Jane
Lucas
Dird no. 3
Fox
Martinka
Nelgs
Seam
Sewlckley
Melgs Creek No. 9
Pitttburgn i.o. E
Pittsburgh No. 8
Pittsburgh
Pittsburgh
Pittsburgh
Pittsburgh
Pittsburgh
Pittsburgh
Upper Freeport
Upper Freeport
Lower Freeport
Middle Kittannlng
Lower Kittannir.g
Lower Kittanning
.oxer Kittanniiig
Clarion 4A
Run
1-3
1-2
1-3
1-2
1-2
1-2
1-2
1-3
1-2
1-2
1-2
1-2
1-2
1-2
1-2
1-3
1-2
1-2
Total
Kxn.
Time
23
23
13-23
23
23
23
23
23
23
23
23
23
12-23
23
23
23
23
23
Mesh*
100
150
100
100
100
150
100
100
150
100
200
100
100
100
150
100
100
100
ORGANIC SULFUR (X M/H)
Initial
0.27
1.088
2.37
-.113
1.34 •
.' . 026
1.36
= .097
0.46
•.074
0.37
1.068
1.21
-.063
0.98
;.120
1.43
-.193
1.27
i.lOO
0.25
-.051
o.«
-.035
0.41
•.051
0.32
:.147
0.22
-.080
0.69
-.044
0.57
i.025
1.48
-. . 046
Final
0.59
1.061
2.81
s.044
2.16
1.182
1.48
-.053
0.65
1.014
0.79
t.041
1.39
'.046
1.25
-.066
2.12
-.014
1.34
-.169
0.69
;.125
0.58
r.103
0.49
1.035
0.55
-.095
0.56
1.080
1.18
= .206
0.38
1.021
1.63
-.061
Difference
+0.32
'.107
+0.44
t.121
+0.82
1.184
+0.12
t.lll
+0.19
i.07«
+0.42
1.079
+0.18
1.079
+0.27
?.148
+0.69
1.194
+0.07
1.196
+0.44
:.135
+0.13
1.109
+0.08
1.062
+0.23
-.175
• 0.34
:.113
+0.49
1.211
-0.19
1.033
+0.15
1.076
calculated
Increase
0.02
0.14
0.09
0.07
0.03
0.02
0.05
0.03
0.09
0.06
0.02
0.02
0.02
0.01
0.01
0.03
0.04
0.10
corrected _
Dlfference
+0.30
1.107
+0.30
1.121
+0.73
1.185
+0.05
i.lll
+0.16
1.075
+0.40
1.079
+0.13
1.078
+0.24
-.148
+0.60
1.194
+0.01
t.196
+0.42
1.135
+0.11
1.109
+0.06
1.062
+0.22
1.175
+0.33
•-.113
+0.46
1.211
-0.23
1.033
+0.05
1.076
Significance Level
fnr Inr routed
>0.0
95
80
95
None
80
90
70
90
80
'lone
80
Hone
.'ione
None
80
90
90
None
>0.1
90
None
95
..
None
90
None
70
80
-
80
--
-
--
70
90
80
--
>0.2
70
-
95
__
-
80
-
None
70
-
70
-
-
-
None
80
Hone
-
>0.4

--
90
..
--
none
-
--
None
--
Hone
--
--
--
-
None
-
-

-------
                                                                                 Table  20   (Cont'd)
Ol
en
Dean
,io. 1
Kopperston No. 2
Harris Nos. 1S2
north River
Orient ,iO. 6
homes teat
Eagle ,,o. 2
Camp Dos. U2
i(en
Star
He 1 don
Edna
liavajo
Belle Ayr
Coistrip
a
Dean
Mas on
Campbell Creek
eagle S No. 2 Gas
Corona
iierrin ..o. 6
i,o. 11
I llinois no. 5
,,o. 9 (;•;. Kentucky)
,,o. 9
No. 9
Des Hoines Ho. 1
«adge
,.o. 6.7,8
Roland-Smith
flosebuc.

1-2
1-3
1-2
1-2
1-2
1-3
1-2
1-3
1-3
1-2
1-2
1-3
1-3
1-3
1-3
1-3

23
23
13
23
23
23
23
13-14
13
23
23
23
23
23
6-10
12-13
fin -~,J -5
150
100
100
100
100
100
100
100
100
100
150
100
IOC
100
100
100

1.32
-.091
1.C6
*.126
0.41
-.055
0.48
±.036
0.57
:.025
0.36
-.100
1.25
*.051
1.61
1.156
1.65
•.130
1.72
-.053
1.50
-.075
1.00
i.069
0.61
'.038
0.50
±.044
0.54
-.035
0.67
±.019
1.75
±.033
1.32
-.133
0.49
+ .041
0.67
-.039
0.70
±.040
0.46
-.095
1.86
±.116
1.68
-.065
1.73
'.066
2.24
i.043
2.06
-.097
1.69
±.161
0.59
±.043
0.57
-.077
0.65
±.030
0.57
±.056
+0.43
+0.26
-.183
+0.08
+0.19
+0.13
+0.10
±.145
+0.61
+ 0.07
•.169
+0.08
'.146
+0.52
+0.56
+0.69
±.175
-0.02
±.057
+0.07
±.089
+0.11
±.046
-0.10
±.059
0.05
0.03
0.02
0.01
0.04
0.01
0.01
0.12
0.09
0.07
0.08
0.10
0.02
0.03
0.02
0.04
+ 0.37
±.097
+0.23
±.183
+0.06
±.069
+0.18
±.053
+ 0.09
±.047
+0.09 "
+ .U5
+0.60
±.127
-0.05
±.16"
-0.01
±.146
+0.45
±.071
+0.48
±.123
+0.59
±.175
-0.04
±.057
+0.04
±.089
+0.09
i . Qt.6
-0.14
±.059
80
70
None
80
70
done
90
None
Hone
90
80
80
Hone
^one
ijone
None
80
None
-
70
None
--
80
-
-
90
80
95
-
-
--
-
70
--
-
None
--
-
80
-
-
80
80
90
-
-
-
-
Hone
-
--
-
-
-
None
-
--
None
None
80
-
-
-
-

                        a!00 mesli x 0 ano 200 mesh x 0 is  symbolized as  100 and 200, respectively.
                         Increase cue to ash removal; see  Tables 18 and  19.
                        Corrected to reduction in ash.
                        dTested ty using £ test; results with a significance of less than 70:; (where o  =• i organic  sulfur)
                         were  not considered statistically important.

-------
                                 Table 21
                     SUMMARY OF ORGANIC SULFUR INCREMENTS*
Coal Basin
All Samples (34)b
Appalachian (23)
Interior (7)
Western (4)
Medi an
0.16
0.22
0.45
0.04
Average
0.22 ± .124C
0.23 ± .127
0.31 ± .286
0.01 ± .100
Low
-0.23
-0.23
-0.05
-0.14
High
+0.73
+0.73
+0.60
+0.09
  Increase  in organic sulfur after leaching and after correction for reduc-
  tion  in ash content.
 lumber of mine samples
 'Pooled standard deviations
      From an analytical point of view, a systematic error of 0.1% is easily
 possible and from a practical perspective, differences less than 0.1% are
 not  important; therefore, the data were tested for statistical significance
 for  differences of  >0.1% w/w.  Using this criterion, six coals had a
 >0.1% w/w organic sulfur increase with a significance of 90 or more per-
 cent, six were significant at the 80% level, and three at the 70% level.
 For  a difference of  >0.2% w/w, two were significant at the 90% level, five
 at the 80% level, and three at the 70% level.  When tests were made for
 significance for differences  >0.4% w/w, only the Weldon and Egypt Valley
 No.  21 coals had 80% or more significance.
     These organic sulfur increases could result from three possible
 sources:  (a) actual organic sulfur increases caused by either sulfonation
 or sulfation reactions, (b) apparent organic sulfur increases caused by
 formation of unextractable inorganic sulfur species during coal leaching,
and  (c) incomplete removal of elemental sulfur in the toluene extraction
step.  Partially oxidized coals, coals with many phenolic groups or other
active sites, or highly porous coals with a large internal surface area
should be prime candidates for sulfonation or sulfation.  Coals of this
type included in the survey are the Western and the Interior Basin coals.
                                    56

-------
In fact, these two groups of coals in general  had  a  higher  ferric ion
consumption (see Table 12) than the Appalachian  coals.   Ferric  ion oxida-
tion of coal should typically produce phenols, alcohols  and other reactive
sites which could easily react with the sulfuric acid present in any extrac-
tion.  Since both of these groups of coals did not show  organic sulfur
increases significantly different from Appalachian coals,  the possibility
of sulfonation or sulfation reactions does not seem likely.
     Apparent organic sulfur increases could result from insoluble  inor-
ganic compounds, such as CaS04 or Fe(OH)S04, precipitating in the  pores
of tightly structured coal, as is the case for most Appalachian coals.
Coals with high pyritic sulfur contents, such as Egypt Valley No.  21,
Weldon, and Fox coals, could produce significant amounts of sulfate inter-
nally which could precipitate as CaSO^ in the coal pores by reacting with
CaO or CaCCL present in all coal ash, or could form insoluble  Fe(OH)S04
under appropriate conditions.  Even  though the analytical procedure for
hydrochloric acid extraction of  sulfate sulfur was designed specifically
to remove sulfate formed  by oxidation or weathering and thus could easily
miss deeply imbedded inorganic material,  it seems unlikely that more than
0.1% sulfate sulfur could  be missed  in the analysis, even  in the Appa-
lachian coals.
     The third possibility is  the  incomplete  removal of the elemental
sulfur in the toluene extraction step.  Elemental sulfur would raise the
total sulfur value but would not result in erroneously  high pyritic or
sulfate sulfur values.  Because  organic sulfur  is calculated by differ-
ence, this additional sulfur would  then result  in a  higher organic sulfur
value.  Since the extraction step  has  not been  optimized and is presently
performed only once, this  source of error should  be  considered an excel-
lent possibility.  In addition,  this residual elemental sulfur would be
expected to be the greatest in the highly structured and  small-pored
Appalachian coals, and less in the more porous  Internal Basin  and Western
coals.  Because actual results follow these  trends,  this  is considered
the probable source of the organic sulfur increase.   Additional experi-
mentation is required to  confirm this possibility and to  establish  tenta-
tive solutions.
                                     57

-------
     In order to distinguish between  these three possibilities, a series
of experiments was  run  using the Warwick,  Fox, Weldon,  Egypt Valley
No. 21, Delmont, and Homestead coals,  which showed organic sulfur increases
of 0.32, 0.49, 0.69, 0.82,  0.44, and  0.61% w/w,  respectively, and repre-
senting both Appalachian  and Interior Basin coals.
     The first group of experiments was  designed to determine whether or
not unextractable inorganic species were being  formed in the pores of these
coals.  Sulfate was first determined  by  the usual  5N HC1 extraction on the
whole coal in order to  establish the  amount of  extractable sulfur.  In a
separate set of experiments, the organic matter was removed by a low tem-
perature oxygen plasma  technique at 150  C, which oxidizes the coal matrix
without significant oxidation of pyrite  to sulfate.  A sulfate determina-
tion was then performed on  the ash using standard procedures.  The results
summarized in Table 22  show that there is no significant difference between
the sulfate found by either procedure.  Thus, it can be concluded that the
organic sulfur increases  are not due  to  the formation of the unextractable
inorganic species in the  coal pores.
     If the increases were  due to  sulfonation or sulfation reactions of
the ferric sulfate  leach  solution, the use of ferric chloride to remove
pyrite should result in np_ organic sulfur increase.  Since this differ-
ence would be most  striking for the Egypt Valley and Weldon coals which
had organic sulfur  increases of 0.82  and 0.69%  w/w, these coals were
extracted in duplicate  with ferric chloride, and the organic sulfur con-
tent was followed as a  function of time.  The results of these experi-
ments,  listed in Table  23,  show a  steady increase in organic sulfur con-
tent in both cases  as the pyrite was  extracted.   In addition, samples taken
at intermediate times which were not  extracted  with toluene had much higher
organic sulfur increases  than those that were extracted once with toluene.
     When compared  to ferric sulfate  leaching,  both coals had slightly
smaller organic sulfur  increases  (Table  23).  These differences, which
were 0.16% w/w for  the  Weldon coal and 0.30% w/w for the Egypt Valley
coal, could be an indication of a  small  amount of reaction of the ferric
sulfate leaching reagent  with the  coal;  but given both experimental and
analysis variables, this  cannot be established using the present data.
                                    58

-------
                    Table 22

SULFATE DETERMINATION ON WHOLE COAL AND PLASMA ASH£
Coal Mine
Warwick
Egypt Valley
Fox
Weldon
% W/W SULFATE
Whole Coal
0.14
0.12
0.09
0.18
Plasma Ashed
0.12
0.22
0.07
0.11
   Determination in  both  cases  by  the standard ASTM
   method and based  on whole  coal  weight.
                    Table 23

   ORGANIC SULFUR CHANGES WITH FERRIC CHLORIDE6

Coal
Egypt Valley



Ferric
Sulfate
Weldon




Ferric
Sulfate

Time (hr)
0.0
2.0
5.5
23.0

23.0
0.0
1.5
4.0
10.0
23.0

23.0
Sulfur Content, % w/w
Pyritic Organic
5.07b
1.01
0.34
0.00

0.38
5.24b
1.73
0.66
0.20
0.00

0.47
1.34b
2.48
1.70C
1.86C

2.16C
1.00b
1.89
2.23
2.26,,
1.53C

1.69C
     All extractions  used the same procedure  as
     the ferric  sulfate  runs; each coal was ex-
     tracted  in  duplicate and the results  averaged.

     Initial  value  for ROM  coal.

     'Extracted with toluene before analysis.
                        59

-------
Thus,  it  is felt that the observed increases are not due to reaction of
the  leaching reagent with the coal, but rather are due to incomplete
removal of elemental sulfur from coal in the toluene extraction step.
      Incomplete removal of elemental sulfur is a logical result of the
experimental method also because no attempt was made to optimize sulfur
removal and only a single toluene extraction was made.  A check for sulfur
recovery on all 34 toluene extracts showed that sulfur recovery averaged
55 ± 15%, compared to 85-97% that is routinely obtained in our bench scale
work*  ' ' where a double toluene extraction and careful sulfur mass bal-
ance is made.   Since a single toluene extraction is sufficient to remove
elemental sulfur from some coals and is obviously inadequate in other
cases, it is important that experimentation be conducted in order to deter-
mine the degree and severity of extraction that are necessary to remove the
elemental sulfur from a wide range of coals.
      Favorable  results obtained  in  vaporization of  residual elemental  sulfur
and sulfate in earlier work on the Meyers Process indicated that similar
treatment of coals which had apparent incomplete elemental sulfur and/or
sulfate removal could lead to significant additional sulfur reductions and
could further verify the source of the organic sulfur increases. Thus, two
examples — the Delmont and Warwick coals —were chosen in which reduction
of the organic sulfur (i.e., removal of remaining elemental sulfur) would
allow the treated coal to meet EPA's most stringent new source standards.
An additional  coal from the Homestead Mine representative of the Interior
Basin, which could be reduced below most Priority 2 and 3 state standards,
was chosen as the third example.  Analyses of these coals before vapori-
zation treatment are shown in Table 24.
     Each of the coals was treated in duplicate in ceramic boats for 3 hrs
at 370°C in a tube furnace under a 1-liter/minute flow of argon or argon/
hydrogen.  The results based on total sulfur analysis listed in Table 25
show that substantial amounts of additional sulfur were removed in all
three cases.  The Delmont and Warwick coals were reduced enough to meet
EPA's new source standards.  The Homestead coal was reduced by a substan-
tial 0.83% indicating that not only all the residual sulfur was removed,
but also most of the residual sulfate.  Note also that the presence  of
                                    60

-------
                              Table 24

           ANALYSIS OF LEACHED AND TOLUENE EXTRACTED  COALS
                     BEFORE VAPORIZATION TREATMENT
Mine
Delmont Mine,
Upper Freeport
Seam
Warwick Mine,
Sewickley Seam
Homestead Mine,
No. 11 Seam
% W/W Sulfur
Total
0.96
0.82
2.38
Pyritic
0.21
0.09
0.22
Sulfate
0.06
0.14
0.30
Organic
0.69
0.59
1.86
Initial
Organic3
(0.25)
(0.27)
(1.25)
aOrganic sulfur content of run-of-mine coal before ferric sulfate
 leaching.
                              Table 25

            ANALYSIS OF EXTRACTED COALS FROM SURVEY PROGRAM
                    AFTER VAPORIZATION TREATMENT9
Mine
Delmont Mine,
Upper Freeport Seam
Warwick Mine,
Sewickley Seam
Homestead Mine,
No. 11 Seam
% W/W Total Sulfur
Starting6
0.96
AS (loss)
0.82
AS (loss)
2.38
AS (loss)
Ar(370°C)
0.80
0.16
0.61
0.21
1.71
0.68
Ar/H2(370°C)
0.64
0.32
0.56
0.26
1.55
0.83
 aAverage of duplicate  runs.
 bFrom Table 24
                                  61

-------
hydrogen in the vaporization gas increased sulfur  removal  significantly in
all cases.  These results essentially prove the  hypothesis that organic
sulfur increases in treated coals are the result of  incomplete toluene

extraction.

     These very promising results indicate that  treatment  of additional
survey coals by this technique could result in significantly lower  sulfur
values of treated coals by removing sulfate in those cases where  it was
high and elemental  sulfur in those cases where its removal was incomplete.
An examination of the data indicates that approximately 20 out of a total
of 35 coals could benefit from this treatment.  In addition, it is  pos-
sible that vaporization could be developed into  a  viable alternative  to

toluene extraction  in the overall process.  This alternative must be
explored in any future research.

4.3.9  Miscellaneous Data

     Table 26 contains miscellaneous data which  were accumulated  during
this survey and which are treated briefly in the paragraphs below:

     The Filtration Rates of the various coals are qualitatively
     shown in Table 26.  These observations are  based on the amount
     of time required to obtain a dewatered filter cake.  A label
     of fast (F) indicates no problem in filtration, with  the rate
     proceeding near the maximum rate of the funnel; medium (M)
     indicates a slower, but still acceptable rate;  and slow (S)
     indicates that unacceptably long times were required  for fil-
     tration.   It was found that the rate of filtration closely fol-
     lows the ash content of the treated coals,  with high  ash coals
     filtering much slower than low ash coals.  In the case of
     200 mesh x 0 coal from the Camp Nos. 1 & 2  mine (No.  11 seam)
     which filters  very slowly, the removal of excess ash  by density
     fractionation  at 1.90 specific gravity changes  its filtration
     rate from slow to very fast.  Thus, the use of  cleaned coal
     could substantially reduce filtration requirements in any com-
     mercial plant.

     Liquid Retention in the form of leach solution  and toluene was
     also determined under a set of standard, but  not optimum,  con-
     ditions and is expressed as g liquid retained per 100 g coal.
     In both cases, the vacuum filtration was continued 3  minutes
     after no more  liquid was visible on top of  the  filter cake.
     Table 26 indicates that in both cases coal  to coal variations
     were within experimental error and toluene  is retained to a
     lesser extent  than the leach solution.  These results are
     consistent with the postulate that the liquid is being held
                                    62

-------
                                Table 26

                           MISCELLANEOUS DATA
Mine
Warwick
Muskimjum
Egypt Valley
No. 21
Powhattan No. 4
Isabella
Mathies
Wi 11 i ams
Humphrey No. 7
Robinson Run
Shoemaker
Delmont
Marion
Jane
Lucas
Bird No. 3
Fox
Marti nka
Meigs
Dean
No. 1
Kopperston No. 2
Harris Nos. U2
North River
Orient No. 6
Homestead
Eagle No. 2
Camp Nos. 1&2
Ken
Star
del don
Edna-
Navajo
Belle Ayr
Colstrip
Seam
Sewickley
Meigs Creek No. 9

Pittsburgh No. 8
Pittsburgh No. 8
Pittsburgh
Pittsburgh
Pi ttsburgh
Pittsburgh
Pittsburgh
Pittsburgh
Upper Freeport
Upper Freeport
Lower Freeport
Middle Kittanning
Lower Kittanning
Lower Kittanning
Lower Ki ttanning
Clarion 4A
Dean
Mason
Campbell Creek
Eagle & No. 2 Gas
Corona
Herri n Mo. 6
No. 11
Illinois Mo. 5
No. 9 (W. Ky.)
Ho. 9
No. 9
Des Moines Mo. 1
Madge
Nos. 6,7,8
Roland-Smi th
Rosebud
tfesh
100
150

100
:oo
100
150
100
100
150
100
200
100
100
100
150
100
100
100
150
100
100
100
100
100
100
100
100
100
150
100
100
100
100
100
Free Sv
T .In.de
4-1/2


4




8




6-1/2


6
1-1/2

5-1/2

7
7

4-1/2

6
5


1
0.5
0
0
0
vel 1 i ng
<



4




8-1/2




5


7
0

3-1/2

5-1/2
7


0
2-1/2
0

0
0
0
0
0
0
Rank
hvAb
hvAb

hvAb
hvAb
hvAb
hvAb
hvAb
hvAb
hvAb
hvAb
hvAb
mvb
hvAb
hvAb
Ivb
hvAb
hvAb
hvBb
hvAb
hvAb
hvAb
hvAb
hvAb
hvAb
hvBb
hvAb
hvBb
hvBb
hvBb
hvCb
hvCb
hvCb
subA
subB
hvAb
hvAb

hvAb
hvAb
hvAb
hvAb
hvAb
hvAb
hvAb
hvA'
hvAb
mvb
hvAb
hvAb
Ivb
hvAb
hvAb
hvBb
hvAb
hvAb
hvAb
hvAb
hvAb
hvBb
hvBb
hvAb
hvBb
hvBb
hvBb
hvCb
hvCb
subA
subB
subB
Liquid Retention
in q/lOOq Coal

25


38
41
43
49

41
40
45
37

43
39

46
38
35

37
29
39

53


30
35






39


30
33
32
33

40
30
30
24

30
27

38
32
33

37
31
27

43


31
27





Fi 1 tration
Rat p
M
F

F
S
S
S
F
M
F
S
M
H
F
F
F
F
S
S
F
M
F
F
i
S
H
M
S
M
M
M
M
F
F
F
Ash
r-.-.t- ^a
H
L

M
H
H
H
L
L
L
H
M
M
M
L
M
L
H
M
L
L
M
L
H
M
I
M
M
L
L
L
L
M
L
L
Low, 0-17%; Medium, 17-27',:; High >27"f; see text for details.
    in the spaces between the coal particles, and that the differ-
    ences between the leach solution and toluene merely reflect
    the fact that toluene is less dense than the leach solution.

    The Free-Swelling Index (FSI) is an indication of the caking
    qualities of a coal and therefore has some importance in
    evaluation of a coal for coking and for use in certain types
    of steam boilers.  The data show that, for coals that have
    high excess reactivity with ferric ion (such as the Eastern
    Interior Basin coals), the FSI is substantially reduced.
    Coals  having little excess reactivity with ferric sulfate
    (such as the Appalachian Basin coals) have little or no change
    upon treatment.  This is consistent with the generally
    accepted idea that slight oxidation of a coal reduces its FSI.

    The Rank of the treated and untreated coals is the same in all
    instances except for the Orient No. 6, Belle Ayr and Navajo
    coals.   Because rank is determined only by heat content for
    hvAb and lower ranked coals, and because rank is quite insen-
    sitive to small btu changes, only minor differences in rank
    should be expected.
                                   63

-------
4.4  FLOAT-SINK TESTING
     Float-sink testing  (washability  studies) were run on thirty-one of the
thirty-five coals by the Commercial Testing and  Engineering Company in
order to determine how conventional float-sink procedures compare  to the
Meyers Process in efficiency of pyrite  removal,  heat  content  change, and
ash loss.  In addition,  information was obtained that can be  used  to eval-
uate a combined two-step process,  involving coal washing followed  by the
Meyers Process, that would produce coal containing minimum  amounts of
pyrite and ash and a maximum heating  value.
4.4.1  Procedures
     The mine samples, representing  20  mines  and coal seams,  were  selected,
sampled and prepared according to the procedures described  in Section  4.2
and Appendix A of this report.  No tests were run on the four samples  from
the Edna, Navajo, Belle Ayr and Col strip mines,  since they  contained less
than 0.3% w/w pyritic sulfur and 1.0% total  sulfur and were judged eco-
nomically unfeasible for removal of pyritic sulfur by washing.
     Five hundred pounds each of the 1-1/2" x 100 mesh, 3/8" x 100 mesh
and 14 mesh x 0 portions prepared from the initial samples of the coals
were fractionated according to standard float-sink procedures using
organic liquids of 1.30, 1.40, 1.60 and 1.90 specific gravities.  Samples
of each size  (head sample), of each gravity portion, and of  the two
100 mesh x 0  samples, were  analyzed on a dry basis for % w/w ash, total
sulfur and pyritic sulfur.
     The raw  data were  then used  to calculate washability data  showing
cumulative recovery and  cumulative reject at the various specific gravities
for each of the  size  portions.  A complete set  of tables showing  all  new
data  is  included  in Appendix  E.   The remaining  data  have been reported
           (2)
previouslyv   .
4.4.2   Results and  Discussion
      Table 27 shows  the summary of the results  for  the 14  mesh x  0  por-
 tions of 1.90 and 1.60  specific gravities and  how they compare to the
 Meyers Process (100 mesh x 0 coal) for the  total sulfur and pyritic sulfur
 reductions and ash removal.  The 14  mesh x  0 float-sink material  was
                                     64

-------
                                  Table 27

                         SUMMARY OF FLOAT-SINK TESTS
                              14 MESH x 0 COAL
                        COMPARISON TO MEYERS PROCESS
                              100 MESH x 0 COAL



Mine Seam
Warwick
Muskingum

Egyot Valley
No. 21
Powhattan No. 4
Isabella
Mathies
Mi 1 1 i ams
lumphrey No . 7
(obinson Run
Shoemaker
Jelmont
torion
Jane
telker
Lucas
3ird No- 3
Fox
Marti nka
Meigs
Dean
NO. 1
Kopperston No. 2
Harris Nos.
1 & 2
North River
Orient No. 6
Homestead
Eagle No. 2
Camp Nos. 1 & 2
Ken
Star

Sewickley
Meigs Creek
No. 9
Pittsburgh No. 8

Pittsburgh No, 8
Mttsburgh
Pittsburgh
Pittsburgh
Pittsburgh
Pittsburgh
Pittsburgh
Upper Freeport
Upper Freeport
Lower Freeport
Upper Kittanning
Middle Kittanninq
Lower Kittanning
Lower Kittanning
Lower Kittanning
Clarion 4A
Dean
Mason
Campbel 1 Creek
Eagle No. 2 Gas

Corona
Herri n No. 6
No. 11
Illinois No. 5
No. 9 (W. Ky)
No. 9
No. 9
Des Moines No 1

Ini tial Analysis
% w/w
otal Pyritic
Sulfur Sulfur ? Ash
1.37 1.09 40.47
6.08 3.65 21.68

6.55 5.07 25.29

4,12 2.57 37.17
1.57 1.07 42.22
1.46 1.05 41.01
3.48 2.23 13.18
2.53 1.59 9.88
4.38 2.89 13.36
3.51 2.19 33.48
4.89 4.56 27.18
1.37 0.90 26.40
1.85 1.44 21.75
0.71 0.07 16.67
1.79 1.42 8.68
3.14 2.87 30.23
3.83 3.09 13.55
1.96 1.61 49.64
3.73 2.19 26.53
4.09 2.62 17.28
3.12 1.98 11.39
0.91 0.47 30.15
1.00 0.49 18.63

2.06 1.42 49.25

4.46 3.11 16.56
4.29 2.64 26.53
4.51 2.30 21.13
4.83 2.85 15.08
4.32 2.60 13.90
6.39 5.24 15.74
Washed Coal Analys s, % w/w
1.90 Float Material
BTU Total Pyritic
Recya Sulfur Sulfur % Ash
93 1.02 0.54 17.02
96 4.36 1.99 19.18

96 4.63 3.42 11.86

93 3.27 1.89 17.40
95 1.48 0.59 14.93
95 1.67 1.02 14.89
98 2.32 0.88 7.87
99 1.90 0.90 6.97
97 3.01 1.24 7.95
96 3.62 2.07 12.23
92 2.13 1.38 10.29
95 1.17 0.58 10.04
97 0.78 0.40 11.15
98 0.66 0.07 12.17
98 0.67 0.32 5.80
93 1.52 0.39 8.80
98 2.00 1.32 8.78
91 0.84 0.46 21.53
95 2.83 1.07 14.10
96 3.05 1.26 12.65
97 2.29 1.03 6.77
95 0.33 0.34 11.31
96 0.92 0.36 13.14

95 2.13 1.08 19.87

97 3.25 1.71 10.61
97 2.92 1.53 12.52
96 2.90 1.22 10.21
97 3.47 1.55 10.02
9C 3.01 1.67 10.47
97 3.91 2.72 8.81
1.60 Float Material
BTU Total Pyritic
ecya Sulfur Sulfur % Ash
89 0.92 0.41 12.96
89 4.17 1.69 16.82

92 4.27 3.03 10.25

88 3.04 1.51 12.37
89 1.40 0.41 9.39
90 1.62 0.93 11.94
97 2.15 0.69 7.09
97 1.S2 0.81 6.45
95 2.81 1.02 7.21
92 3.22 1.60 8.62
90 1 .84 1 .09 8. 72
91 1.10 0.50 7.98
95 0.70 0.31 9.40
93 0.66 0.07 9.59
97 0.62 0.27 5.04
91 1.40 0.75 7.25
95 1.90 1.21 7.44
85 0.75 0.30 14.69
91 2.67 0.84 11.00
92 2.98 1.20 11.69
96 2.15 0.88 6.3
92 0.79 0.28 9.12
89 0.87 0.30 =>.5

91 2.07 0.93 11.8

95 3.07 1.50 9.!
94 T.77 1.35 10.4
91 2.75 1.01 8.4
96 3.37 1.44 9.46
97 2.92 1.57 10.0
95 3.81 2.60 8.2
b
Final Analysis , % w/w
BTU Total Py-ntic
Recya Sulfur Sulfur S Ash
99 0.66 0.06 35.32
97 3.22 0.24 16.05

93 :.71 0.33 18.69

100 1.94 0.04 32.13
100 0.72 0.06 35.72
'r'0 0.94 0.05 36.43
99 1.74 0.29 9.16
99 1.49 0.14 66.97
98 2.20 0.08 7.63
99 1.73 0.08 28.87
98 0.96 0.21 20.44
100 0.68 0.04 22.61
98 0.69 0.14 17.99
c c c c
100 0.63 0.07 6.32
98 0.80 0.13 24.17
9C 1.64 0.26 9.72
(93) 0.58 0.12 43.46
98 1.94 0.17 20.38
99 • 2.08 0.17 13.66
9S ,.r-2 0.21 3.50
;%) 1.61 0.04 25.53
9° .77 0.04 16.46

(04) 0.93 0.14 42.84

96 :.3S 0.22 11.50
97 1.97 0.11 19.49
98 2.02 0.14 15.77
97 2.78 0.28 9.44
96 2.46 0.06 8.58
94 2.25 0.15 5.94
   aSee text for method of calculation of recovery (Recy)
   Best run
   cNot run due to low pyritic sulfur
chosen  even though it may  be  too  fine to be used in a commercial  installa-
tion, because in most instances the best results were obtained with this
top size.   A series of telephone  contacts was made with all  the mine
operators  in this study  in order  to verify this assumption.   These con-
tacts indicated that, of those mines which also clean coal  before ship-
ment, that the resulting sulfur and ash contents obtained from the
1.90 float 14 mesh x 0 material are roughly equal to the sulfur and ash
                                      65

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contents of the coal  presently being  shipped  from  the  corresponding  prepa-
ration plants.  The 1.60 float data  are included to illustrate what can be
produced from a coal  preparation  plant  with a sharply  increased  reject
fraction.  In addition, the current  trend  as  the result of the current
coal (and energy) shortage has been  to  decrease rejects, with concomitant
increasing of the sulfur and ash  content,  in  order to  increase production.
For these reasons, it is felt that the  1.90 float  14 mesh x 0 fraction
represents a conservative basis for  comparing the  efficiency of coal
cleaning to the Meyers Process.
     In several cases, including  the Humphrey No.  7, Marion, Dean,  Eagle
No. 2, Ken and Star mines, the 38.1  mM  x 149y (1-1/2"  x 100 mesh)  portions
gave similar or slightly better results than  the 1.41  mm x 0 (14 mesh x 0)
portions, while better results were observed  with  the  coarse fraction for
the Shoemaker, Meigs, Homestead and  Weldon coals.   With all other coals,
coal cleaning potential decreased when  coarser material was washed.
     The percent float-sink btu/lb loss (see  Table 27  for tabulation of
results) was calculated from the  percent w/w  and ash content of the cumu-
lative material which.was rejected at the specific gravity of interest.
This value was assumed to represent the total heat content loss and was
subtracted from 100% to give the  btu recovery.  Complete organic material
recovery was assumed for the Meyers Process because no evidence has been
found to date that indicates material other than ash is dissolved in the
leaching process.  The percent recovery was then calculated using the
before and after dry-mineral-matter-free heat content of the coal.
     The analysis of the 1.90 float material  shows that 0.0-1.9% w/w more
total sulfur is removed from the  coal by the Meyers Process than by the
float-sink method, with a median  value of 0.7% w/w.  For the  1.60 float
material, the corresponding figures are 0.0-1.6% w/w with a median value
of 0.6% w/w.  The majority of the remaining total sulfur values obtained
for both specific gravities were between 0.4 and 1.0%  higher  by the float-
sink method than by the Meyers Process.
     The advantages of chemical leaching are even more  apparent in the
final pyritic  sulfur values where, for all but one coal,  the  final values
are between 0.0 and 0.3% w/w.  Float-sink  separation at a  specific gravity

                                     66

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of 1.90 resulted in final pyritic sulfur values of  0.3  to  3.4%, which drop
to 0.3 to 3.0% at a specific gravity of 1.60.   The corresponding median
values are 1.1 and 1.0% w/w, respectively.   The 1.90  float material of the
low sulfur Harris Nos. 1 and 2 and Kopperston No. 2 mines  as well as the
Warwick, Jane, Lucas and Martinka mines had final pyritic  sulfur values of
0.3-0.5%, making them possibly competitive with the Meyers Process.  Note,
however, that 90% pyrite removal is not always reflected in the total sul-
fur values due to slight increases in other sulfur  forms.  Although for
approximately one-half of the coals the Meyers processing  results are
already near optimum  (see Table 1), additional processing  improvements will
be necessary to reach near optimum values for the others.  However, in all
cases the Meyers Process reduced the total  sulfur content of  the coals
lower than that obtainable by conventional  coal cleaning.   In  most cases,
the differences were  substantial.
     The heat content recovery for the 1.90 float material is  96 ±2% and
for the 1.60 float material, it is 93 ±3%.  In contrast, chemical  leach-
ing results in 99 ±1% recovery for the Appalachian  coals and  96 ±3% for
the Eastern and Western  Interior basin coals.  Thus,  chemical  leaching and
washing the Interior  Basin coals at a specific gravity of 1.90 result  in
comparable heat losses,  while in all other categories the Meyers Process
is superior with respect to heat content recovery.   In addition,  oxidation
of the coal during the leaching process results in an in  situ generation
of heat which can be  used to supply process heat requirements for  the
Meyers Process, while losses due to washing are discarded with the refuse
and in some cases may even present a fire  hazard.  Thus,  for almost every
coal, the Meyers Process is more efficient than physical  separations  with
respect to energy recovery.
     Table 27 also summarizes ash changes as  the result of both processes.
Note that in most cases, especially the Warwick, Isabella, Mathies, Shoe-
maker, Bird No. 3, Martinka, Kopperston No. 2 and  North River mines,  sub-
stantially more ash is removed  by physical cleaning compared to the Meyers
Process (in which only ash corresponding to pyrite is removed).  Only in
low ash cases, such as the Fox, Williams,  Humphrey No.  7, Robinson Run,
Lucas, Fox, Dean, No. 1, Homestead, Ken, Star,  and Weldon coals, are both
                                    67

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 processes  comparable.  With the Walker coal, which has essentially zero
 pyritic sulfur, only ash reduction was achieved.  However, ash reduction
 in itself  is valuable in that reduced shipping costs, reduced load on
 electrostatic precipitators and enhanced heating values are realized.  In
 addition,  a certain part of the ash is soluble in the leach solution of
 the Meyers Process and any initial ash reduction should reduce both puri-
 fication requirements on this solution and, depending upon pyrite reduc-
 tion, on operating costs of the Meyers Process.  Thus, depending on the
 situation, a simple cleaning procedure on most coals, and especially those
 containing >15% w/w ash, would be advantageous prior to treatment with the
 Meyers  Process.
 4.5  REMOVAL OF TRACE ELEMENTS
     In the last few years, the potential environmental hazards of trace
 elements emitted in the flue gas from coal combustion has become a matter
           (9-14)
 of concern      .   In view of this interest, it seemed appropriate to per-
 form a survey of trace element concentrations in the coals selected for
 this project, and to examine removal efficiencies by both the Meyers Process
 and physical  cleaning.  This has been accomplished for 20 coals representa-
 tive of the Appalachian, Eastern Interior and Western coal basins for the
 elements Ag,  As, B, Be, Cd, Cr, Cu, F, Hg, Li, Mn, Ni, Pb, Sb, Se, Sn, V,
 and Zn.
 4.5.1  Analysis,.Procedures, and Results
     In selecting procedures for the elements of interest, three major
factors were considered.  First, a sensitivity of 1 ppm (dry weight of
whole coal) was selected as the lowest possible level of interest with
 the exception of Hg, where 0.1 ppm was used.  This value was selected on
 the basis that if 100% of the element were emitted from the stack, 1 ppm
 in the feed coal would result in an emission of only 45 g/hr (0.1 Ib/hr)
 from a 100 MW utility which, by all available information, seemed to be a
 conservatively safe emission level.  Secondly, the analytical method
 chosen should have an overall accuracy of ±10% so that removal efficien-
 cies could be accurately determined.  The third factor considered was cost.
 On the basis of the survey nature of this task and the uncertain environ-
 mental hazards associated with the selected trace elements, it was decided
                                    68

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that extensive methods development studies were not warranted and that
relatively  inexpensive procedures should be used.  In several cases, the
first two requirements were relaxed where added costs of meeting the
requirements  seemed excessive for the added value.  Based on these cri-
teria, all  the trace analyses except those for As, B and F were performed
using atomic  absorption spectroscopy.  The elements As and B were deter-
mined spectrophotometrically, while F was determined using a specific ion
electrode technique.  Details of the procedures and all of the raw data
from the analyses are presented in Appendix F,  In the case of Se, the
method chosen appeared to perform well only on occasion and the results
are so mixed  that all of the data presented is highly suspect.  Several
studies are currently being conducted on a reliable Se method for coal.
     The aforementioned procedures have been checked by comparing TRW
analysis results of NBS Sample 1632 with NBS reported values and are sum-
marized in Table 28.  Recently, a large scale interlaboratory comparison
of trace element results for coal using SRM 1632 was completed by the
U.S. Environmental Protection Agency and the National Bureau of Standards'  '
The mean values obtained from all other participating laboratories for the
trace element concentrations are also included in Table 28.
     Referring to Table 28, it can be seen that analyses for elements As,
Be, Cu, Hg, Mn, Ni, Pb and Zn all show fair to excellent agreement with
the certified NBS values both in accuracy and precision.  The value
obtained for  vanadium is in good agreement with the reported NBS value;
however, the  precision between replicate samples  is poor.  This poor pre-
cision is not indicative of the precision normally obtained with coal
samples, which is typically ±24% relative deviation.  The value obtained
for Cr is approximately 18 ppm higher than the NBS reported value, which
might be attributed to contamination or incorrect background correction.
The cadmium value reported by TRW is 2 ppm higher than the NBS reported
value.  However, the range of values reported is approaching the lower
limit of detectability for this element by AAS and for this reason will
show a large degree of scatter and inaccuracy.  The difficulty with the
Cd analysis is not limited to the TRW results, since all laboratories had
difficulty with this analysis; this is apparent when the mean value of
0.9 is compared with the NBS certified value of 0.19.  No fluoride values

                                    69

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                                   Table 28
                   COMPARATIVE TRACE  ELEMENT ANALYSIS  RESULTS'
                          (PPM IN MOISTURE-FREE COAL)

As
Ag
Cd
Cr
Cu
Hg
Li
Mn
Ni
Pb
Se
Sb
Sn
Tl
Th
U
V
Zn
fe
Be
F
B
NBS 1632
Certified
Values
5.9 + 0.6

0.19 + 0.03
20.2 +0.5
18 + 2
0.12 + 0.02

40 +_ 3
15 + 1
30 + 9
2.9 +_ 0.3


0.59 +_0.3
(3)e
1.4 + 0.1
35 +_ 3
37 +_4
8700 + 300
(1.5)e


EPA-A11 Labs
Grand Mean
6.24

0.9d
22.7

0.22

41.3
19.0
30.4
4.6




1.7
34.9
29.5d

1.75
83. 5d

TRW
5.0 +_0.64
1 +.0.7
2.4 +_0.14
38 +2.8
15 + 1.4
0.10 +. 0.0
28 +_ 0.0
39 i 1.4
18 +_0.7
30 +_ 1.4

4.8 +^ 3.2
4 +_ 5.2



32 +_ 20
33+1.4

2.0 +.0.1
73 +_7
32 + 11
Illinois State Geological Survey
Neutron
Activatior
5.7




0.18

39


2.8











Atomic Absorption
LTA


<0.4
24
18



16
22







40




HTA


<0.4
22
23



16
32







38




Optical
umssion



22
28



26
24

0.2C
2C



54


1.72

43C
X-Ray
Fluor.




22



22
26







49
1.12



Ion
Elec.




















80.4

   aTable taken from Reference 8; TRy values added.
    Average of at least four or more determinations.
   cValues reported separately in Reference 8.
    Oruestionable mean; wide scatter or limited data.
   elnformation value only.  Not certified by NBS.
are reported by NBS;  however, several  spiked samples were analyzed to
check  the procedure employed for recovery of added  fluoride.   The percent
recovery obtained was  85%, suggesting  that TRW  reported values might be
slightly lower than the  true value.  Analysis results which have recently
been reported by the  Illinois Geological  Survey (IGS) for SRM  1632 have
included additional results for F,  B,  Sn, and Sb.   TRW results are in
good agreement for F,  B,  and Sn but are in poor agreement for  Sb.  There
are no comparative analyses available  for the elements Ag and  Li, so no
comment can be made as to the relative accuracy of  the procedures
employed.
                                       70

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     The results of trace element analyses for 18 elements  in  10  coals
before and after treatment by the Meyers Process and by deep cleaning are
presented in Appendix F, Tables F-2 through F-ll.  The first group  of
10 coals was reported in the final report^ ' of the preceding  coal  survey
program and are included only in summary here.  A summary of the  trace
element levels in the untreated coals appears in Table 29.  The analyses
were run in triplicate for the first survey program and in  duplicate on
both untreated and treated coals for the present survey program.   The
change from triplicate to duplicate analyses was a cost saving step but
resulted in slightly less precision for the second phase of the program.
     Up to 22 sets of calculated standard deviations (a) for  each element
in the untreated coal were used to calculate a pooled standard deviation
(S) for each element.  The same was done for coal extracted by the Meyers
Process and for the washed coal.  The pooled standard deviation is calcu-
lated as follows:
                                                   2
                    s   =                    ..... Vn
 where
      a  =  standard deviation  for  a  given  set  of analyses
      
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                                                      Table 29

                                   TRACE  ELEMENT COMPOSITION OF UNTREATED COALS (PPM)

Ag
As
B
Be
Cd
Cr
Cu
F
Hq
L1
Mn
N1
Pb
Sb
Se
Sn
V
Zn
Appalachian Coal Basin
Egypt
Bird Valley Humphrey
Musklnaum Mathles Robinson Powhattan Delmont Mai*1on Lucas 13 Mefgs 121 Jane Fox Warwick 17
2.3 1.8 1.6 0.8 2.6 1.5 2.0 2.9 0.6 4 2 <0.1 4 0.5
2.0 6,1 5.9 4.3 40 98 74 16 2.6 22 29 24 13 9
54 54 60 62 18 10 20 30 115 34 27 16 20 26
2.0 2,7 0.6 3.3 4.2 2.2 3.8 3.6 1.4 0.7 0.8 2.0 1.0 0.4
1.6 0.8 1.8 1.2 1.8 1.5 1.4 1.4 0.8 <0.5 <0.5 <0.5 <0.5 <0.5
110 110 100 141 144 76 52 149 100 55 55 94 81 26
15 29 10 25 20 38 13 26 23 26 35 25 24 16
117 210 100 282 131 155 65 105 222 168 122 94 251 78
0.09 0.09 0.14 0.07 <.02 0.06 <0.2 0.10 0.05 0.31 0.11 0.07 0.14 0.06
55 64 12 52 24 76 8 54 22 26 38 4 76 13
25 66 42 57 94 25 15 45 44 41 46 24 31 31
29 34 26 37 68 23 35 36 22 41 33 147 44 17
12 19 12 20 31 15 18 23 12 15 25 5 16 7
<5 <5 19 <5 16 <5 <5 <5 9 <5 <5 <5 <5 <5
59 74 49 54 25 8 63 <5 <5 17 <5 <5
15 12 8 <5 20 <5 10 15 15 <5 <5 <5 <5 <5
33 60 28 60 40 54 12 60 50 102 147 94 78 77
30 41 30 40 76 34 50 80 38 31 34 105 55 18
Eastern Interior Basin
Eagle Orient Camp Nos.
Ken #2 16 142
1.4 <0.1 <0.1 8
6.5 6.6 15.2 5.7
6.0 30 43 272
2.0 0.5 6 1.5
1.7 0.5 0.7 0.8
76 126 74 122
16 18 36 17
124 151 105 215
<0.2 0.16 0.12 0.16
9 4 23 10
60 86 57 98
30 136 53 27
16 29 0.5 25
24 <5 <5 <5
15 <5 <5 <5
12 <5 <5 <5
35 64 69 105
40 215 25 97
Western Coals
Belle
<0.1 <0.1
0.4 
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                                 Table 30
                    TRACE ELEMENT ANALYTICAL PRECISION
Element
Ag
As
B
Be
Cd
Cr
Cu
F
Hg
Li
Mn
Ni
Pb
Sb
Se
Sn
V
Zn
Average
Concentration
(ppm)
2.5
11.4
48.1
2.0
1.3
71.3
20.4
125.2
0.13
25.1
39.7
43.5
23.0
12.0
18.3
26.0
58.0
51.4
Pooled Standard Deviation (ppm)
Untreated
Coal
1.32(15)*
1.78(21)
3.85(22)
0.39(19)
0.26(21)
4.26(20)
2.18(22)
11.18(21)
0.03(18)
3.77(21)
4.74(22)
6.16(22)
3.51(21)
5.77(8)
5.91(5)
9.91(7)
15.81(22)
5.25(22)
Meyers Process
1.91(12)
1.22(12)
5.49(19)
0.20(19)
0.42(9)
4.10(20)
3.08(19)
18.50(19)
0.054(9)
3.65(20)
2.44(20)
6.15(19)
7.19(19)
3.96(4)
1.15(2)
9.14(8)
14.98(19)
4.73(20)
Float Sink
0.16(5)
1.80(8)
1.96(10)
0.52(9)
0.63(10)
1.83(10)
1.76(10)
8.57(9)

1.11(10)
1.74(10)
7.94(10)
4.38(10)
7.17(10)

9.94(10)
4.98(10)
3.02(10)
All
Samples
1.48
1.64
4.59
0.36
0.42
3.83
2.49
14.13
0.04
3.36
3.52
6.54
5.35
6.19
5.03
9.68
14.01
4.69
% Relative
Standard
Deviation for
All Samples
59
14
10
18
32
5
12
11
31
13
9
15
23
52
27
37
24
9
    *Values in parenthesis are numbers of sets of data used in the calculations.
In keeping with  the  low  levels  at which these elements were present, the
percent relative deviations  of  these  analyses were generally high:
Ag, ±59%, Be, ±18%,  Cd,  ±32%, Hg,  ±31%.
     Seven of the  remaining  elements  (As,  Cu, Li,  Pb,  Sb,  Se and Sn) were
generally present  in the range  of 3-30 ppm,  while  the  remaining seven
(B, Cr, F, Mn, Ni, V and Zn) were generally  above  30 ppm.   The analytical
precision of these fourteen  elements,  while  not as good as had been hoped,
was generally acceptable:  As,  ±14%,  B,  ±10%, Cr,  ±5%, Cu, ±12%, F, ±11%,
Li, ±13%, Mn, ±9%, Ni, ±15%, Pb,  ±23%, Sb, ±48%, Se, ±32%, Sn, ±38%,
V, ±24%, Zn, ±9%.
                                     73

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4.5.2  Removal Efficiencies
     The removal efficiencies for trace elements from coal  treated by the
Meyers Process and by physical cleaning are summarized in Table 31.  A dis-
cussion of the results on an element-by-element basis is presented in this
section.
     Ag  -  Due to the low values of Ag present in coal and the poor pre-
            cision of the results, the data for Ag are somewhat inconclusive.
            However, in over half of the cases where there is a decided
            difference after treatment, 50% or more of the Ag has been
            removed.
     As  -  Arsenic is easily and effectively removed by both treatments
            in almost every case.  The Meyers Process is slightly more
            effective and removed at least 80% of the As in every case.
     B   -  Boron is not appreciably removed from coal by either process
            except in isolated cases.
     Be  -  Beryllium is not appreciably removed by either process except
            in isolated cases.
     Cd  -  Due to the low values of Cd present in coal and the poor  pre-
            cision of the results, the data for Cd are  somewhat inconclusive.
            The data suggest  that Cd is removed by the  Meyers  Process,
                     —  	                     (9)
            which is consistent  with the reportedv '  presence  of  Cd  in  the
            ZnS phase, since  Zn  is easily  removed.  The values for washed
            coals are inconclusive.
     Cr  -  Chromium is removed  by both treatments in almost every case
            by  50% or greater.
     Cu  -  Copper  is only moderately  removed  by  either process.
     F   -  There  is only  limited evidence of  fluoride removal by the
            Meyers  Process.   Washing,  however,  shows  30-60% removal  in
            nearly  every case.
     Hg  -  Due to  the very  low (0.1  ppm)  levels  of  Hg in  all  coals exam-
            ined, no data  on removal are available.
                                     74

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                                                                                           Table  31
                                                                          TRACE   ELEMENT  REMOVALS  (%  W/W)
Element
Ag

As

6

Be

Cd

0

Cu

F

Hg
U
Mn
N1

Pb

Sh

Se

Sn

V

In

Condition
M'b
Fsb
M
Fs
M
Fs
M
Fs
M
Fs
M
Fs
M
Fs
M
Fs
M
Fs
M
Fs
M
Fs
M
Fs
M
Fs
M
Fs
K
Fs
M
Fs
M
Fs
M
Fs
Appalachian Coal Basin
Robinson Powhattan Bird Egypt Humphrey
Muskinaum Mathies Run M Oelmont Marion Lucas »3 Meigs Valley Jane Fox Warwick *7
83+17 89+3 NDC Gaind NO >33 ND NO Inde 50+15 ND NO NO NO
>57+?0 44+16 3315 ND 62+8 -33 :-50 66+24 Ind
84+1 ^'95+1 98+1 97+4 81+1 98+1 85+6 81+7 94+5 -.100 91 + 1
97+3 88+_l 73+2 18+8 81+1 75*3
NO NO NO Gain ND ND ND 50+1.3 13+5 HO 70+2 19+9 ND 38+9
44+_7 ND ND 19+;5 72+5 ND ND 92+1 15+6
ND 33+8 ND 30+9 17+5 ND ND 28+1 NO 43+16 38 70+14 ND NO
Gain ND ND fiD 52+2 54+3 21*4 Gain 29+18
67+J4 >38*24 ND ND 33*41 .57 ND 36+20 >38 Ind Ind Ind Ind Ind
Gain Gain Gain G.iin Gain • ND ND ~ND ND
53*8 49+4 63+1 40+2 44+fi 50*5 48+3 59+3 52+1 ND 60+14 58+5 41+4 ND
45*8 56+3 70+.2 56*1 64+1 37£3 48+3 62+1 50+1
ND 24+8 Gain ND ND 50+1 Gain 58+9 39+5 35+9 11+4 44+6 ND ND
dain 34J7 Gain 20+.15 45*2 42+6 38+5 38+TO 52+/1
Gain ND ND 23+1 NO ND 11+5 ND ND 21+9 ND 12+2 33*6 ND
26+7.2 58+5 ND 59*_1 59*3 48+3 36+6 54+6 6S+2
NO ND Gain 43+23 Gain
ND 38*7 33*23 10*4 NO 18-1 25*9 NO NO NO 92*2 Sain 21-6 NO
72*18 59+6 58*"15 67+3 58»3 64*1 50+9 70+7 5 HZ
75+9 90+4 83+3 72+1 S8+1 70+3 56+14 80+3 64+85 Ind Ind
~
ND .'58*10 Ind Gain N0 Gain ND :8+22

ND ND Ind

67+36 Ind Ind Ind
Ga i n
4ira ND ND ND
20+14
58+7 84+1 82*4 55+J8
10+3
Western Coals
Belle
Ayr Colstrip
!nd Ind

NO Ind

NO 86+E

Ind Ind

Ind Ind

Gain Gain

19+.7 ^a'"

44+9 ND

41+7 NB
Gain Gain
92+25 93^.3
89+6 58*5

Gain 93+^11

Ind Ind

ND Ind

Ind Ind

Gain 98+11

95+_l ND

tn
           aM«100 mesh x Ot a finer ROM coal treated by the Meyers Process

           bFs=1.90 float fraction of  14 mesh x 0 coal treated by float-sink methods

           cND=no statistically significant difference between initial and  final  values.

            Gain-treated coal showed increase in trace metal content.

           elnd»both initial and final values near or below level of  detectability.

-------
     Li   -  Lithium  is  removed  in only a few cases by the Meyers Process
            but shows 50-70% removal by washing in nearly every case.
     Mn  -  Manganese is  easily and effectively removed by the Meyers
            Process  by  60-90% in most cases.  Washing is nearly as effec-
            tive but seems  to remove slightly less than 40-70%.
     Ni   -  Nickel is removed by the Meyers Process by 30-70% in most coals.
            Washing  does  not appear to be  effective.
     Pb  -  In several  cases Pb shows excellent removal (70-90%) by  the
            Meyers Process.  For cases where both processes  are analyzed,
            neither  appears to  be effective.
     Sb  -  Due to the  low  values of Sb present in coal and  the poor pre-
            cision of the results,  the data for Sb are inconclusive.  How-
            ever,  in those  cases where there is a high Sb concentration
            in the starting coal, Sb is effectively removed  by  the Meyers
            Process  and to  a lesser extent, by washing.
     Se  -  No conclusion can be drawn due to the difficulties  with  the
            analyses.
     Sn  -  Tin shows little signs  of being removed by either  process.
     V   -  Vanadium shows  moderate removal by  either process,  with
            slightly better results by washing.
     Zn  -  Zinc is  easily  and  effectively removed  by either process in
            almost every case.  The Meyers Process  appears  more effective
            (70-90%) than washing  (30-40%).
4.5.3  Summary and Conclusions
     Analyses of 50  coal  samples,  consisting of 20  as-received, 20 chemically
extracted using the  Meyers  Process, and  10 undergoing float-sink separation
have shown that both float-sink procedures and  the  Meyers Process are able
to remove significant  amounts  of  several  trace elements.   Although results
vary from coal to coal  as to  elements  extracted and the  degree of extrac-
tion, some general  conclusions  can be  reached.
     •  Elements commonly found in nature as  sulfides are the calco-
        phile elements, which  include  As, Co,  Cu, Ni, Pb and Sb.  The

                                    76

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Meyers Process appears to be more efficient than float-sink
procedures in removing these elements.  The Meyers Process
has demonstrated removal of As, Cu, Ni, Pb, and Sb, whereas
float-sink procedures removed only As, Cu, and Sb.
A positive correlation has been demonstrated between Zn and
                               (9)
Cd in Illinois coals by the IGSV '.  These two elements are
believed to be present in the host phase ZnS.  Both Zn and
Cd are removed with the Meyers Process, but only Zn removal
was demonstrated by float-sink.  Coals extracted by the
Meyers Process generally exhibited a much higher rate of Zn
removal than float-sink samples which could account for the
accompanying increased number of samples exhibiting Cd
removal.  Because Cd is present in all of the tested coals
in amounts less than 2 ppm, it is statistically difficult
to observe the smaller changes in concentration that would
be expected as the result of float-sink separation.
Float-sink procedures were found to extract significant
amounts of Li and F which were not removed to any signifi-
cant degree by the Meyers Process.
The elements As, Cr, Mn, Ni, and Zn were found amenable to
removal by the Meyers Process in over 65% of the coals
tested.  The degree of extraction was found to vary from
coal  to coal, however, with As registering removals varying
from 81-100%; Cr, 23-71%; Mn, 44-93%; Ni, 27-89%; and
Zn, 47-95%.  Ag, Cd, and Sb also appear to be effectively
removed by the Meyers Process; but due to their low con-
centrations, the data are inconclusive.
Float-sink procedures accounted for a larger number of ele-
ments being significantly removed.  Again, the results
were variable from coal to coal.  Ag was found to be
removed in the range 28-66%; As, 18-97%; Cr, 37-70%;
Cu, 20-88%; F, 28-69%; Li, 33-72%; Mn, 20-96%; and Zn,
10-70%.
                            77

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     •  The elements Pb and Cd were not removed from the coals using
        float-sink procedures.  Sn also registered no losses.   How-
        ever, because of the large gains in Sn concentration found in
        the washed coals, it is suspected that contamination occurred
        during washing.  This could be a result of Sn extracted from
        the soldered joints in the metal containers used in these
        separations by HC1 present due to slight hydrolysis of the
        chlorinated float-sink solvents.
     •  Three mines (Mathies, Ken, and Delmont) showed the largest
        number of elements removed (14, 15 and 14, respectively).
     In conclusion, the Meyers Process as well as float-sink procedures
are potentially viable techniques for the removal of a number of poten-
tially hazardous trace elements.  This study indicates that Ag, As, Cd,
Cr, Mn, Ni, Zn and Sb are removed by the Meyers Process in significant
amounts for the majority of the coals tested.  Float-sink procedures have
been shown to also be useful for the reduction of Ag, As, Cr, Cu, F, Li,
Mn and Zn in the majority of the coals tested.  The effective removal of
As, Cd, Cr, Sb, Ni, and Zn from coal is especially noteworthy, as these
compounds are reportedly concentrated (along with Pb and Se) in the fine
                                                (9-12)
particulate emitted from coal-fired power plantsv    '.  This fine par-
ticulate has been demonstrated to pass through conventional particulate
control devices.
                                     78

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                           5.0  ACKNOWLEDGMENTS

     The following TRW personnel deserve acknowledgement:  W.P. Kendrick
and D. Kilday for experimental assistance; E.A. Burns and R.J. Ottinger
for technical assistance; J.L. Blumenthal and B. Dubrow for managerial
assistance; and S. Quinlivan for report editing and coordination.
     The Program Manager for this study at the Systems Group of TRW Inc.,
was Robert A. Meyers, and the monitoring Project Officer for this Environ-
mental Protection Agency contract was Lloyd Lorenzi, Jr.  Appreciation is
expressed to Mr. Lorenzi for his guidance and encouragement.  Messrs.
I. Foster and R. Kaplan of the Commercial Testing and Engineering Company
(Chicago, Illinois) deserve special recognition for their cooperation in
expediting coal sampling and analyses for TRW at CT&E.
                                     79

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                             6.0  REFERENCES

1.  Hamersma, J.W., E.P. Koutsoukos, M.L. Kraft, R.A.  Meyers,  G.J.  Ogle,
    and L.J. Van Nice, "Chemical Desulfurization of Coal:   Report of
    Bench-Scale Developments," EPA R2-73-173, prepared for the Office
    of Research and Monitoring of the Environmental Protection Agency,
    Research Triangle Park, N.C., February 1973.
2.  Hamersma, J.W., M.L. Kraft, C.A. Flegal, A.A. Lee, and R.A. Meyers,
    "Applicability of the Meyers Process for Chemical  Desulfurization of
    Coal:  Initial Survey of Fifteen Coals," EPA-650/2-74-025, prepared
    for the Office of Research and Monitoring of the Environmental  Pro-
    tection Agency, Research Triangle Park, N.C., April 1974.
3.  Koutsoukos, E.P., M.L. Kraft, R.A. Orsini, R.A. Meyers, M.J. Santy,
    and L.J. Van Nice, "Program for Bench-Scale Development of Processes
    for the Chemical Extraction of Sulfur from Coal,"  EPA Contract
    No. 68-02-1336, prepared for the Office of Research and Monitoring
    of the Environmental Protection Agency, Research Triangle Park, N.C.,
    in press.
4.  "1973 Keystone Coal Industry Manual," Mining Information Services,
    McGraw-Hill Mining Publication, McGraw-Hill, Inc., New York, 1973.
5.  Averitt, Paul, "Coal Resources of the United States," Bulletin 1275,
    Bureau of Mines, U.S. Department of the Interior,  1969.
6.  "1971 Book of ASTM Standards, Gaseous Fuels; Coal  and Coke," Part 19,
    American Society of Testing and Materials, Philadelphia, Pa., 1971.
7.  Youden, W.J., "Statistical Methods for Chemists," John Wiley & Sons,
    New York, p. 119, 1951.
8.  Bauer, E.L., "A Statistical Manual for Chemists," Academic  Press,
    New York, p. 61, 1971.
9.  Final report, "Occurrence and Distribution of  Potentially  Volatile
    Trace Elements in Coal," R.R. Ruch, H.J. Gluskoter and N.F.  Shimp,
    EPA-650/2-74-054.
                                    80

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10.   J.W.  Kaakinen, R.M. Jorden, and R.E. West, "Trace Element Study in  a
     Pulverized Coal Fired Power Plant," Paper No. 74-8 presented at the
     67th APCA Annual Meeting, Denver, Colorado, 1974.
11.   A. Lohr, A.H. Miguel, D.F.S. Natusch, and J.R. Wallace, "Preferential
     Concentration of Toxic Species on Small Airborne Particulates," Paper
     No. 74-201 presented at the 67th Annual APCA Meeting, June,  1974.
12.   R.E.  Lee, Jr.,. and D.J. von Lehmden, "Trace Metal Pollution  in the
     Environment," J. Air Pollution Control Assoc. 23 (10):  853, 1973.
13.   D.F.S. Natusch, J.R. Wallace and C.A. Evans, Jr., "Toxic Trace
     Elements:  Preferential Concentration in Respirable Particles,"
     Science  183  (4121):  202,  1974.
14.   C.E. Billings, A.M. Sacco, W.R. Matson, R.M. Griffin, W.R. Coniglio
     and R.A.  Harley, "Mercury  Balance on a Large Pulverized Coal-Fired
     Furnace," J. Air Pollution Control Assoc. 23(9):  773, 1973.
                                     81

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                7.0  GLOSSARY  OF ABBREVIATIONS AND SYMBOLS
Abbreviations
    Abs
    ASTM
    btu
    cal
    eq
    Exp.
    Kcal
    ml
    ppm
    Rxn.
    wt

Symbols
    C
    A
    u
    M
    mM
    N.
    P
    R
    S
    S°
    S_
     o
     T
     t
     V
     W
absolute
American Society for Testing and Materials
British Thermal Unit
calories
equation
experiment
kilocalories
milliliter
parts per million
reaction
weight
concentration
difference  in quantity  following delta
micron
molarity
millimole
normality
total  pressure,  atmospheres
gas constant, cal/mole,  K
sulfur
elemental  sulfur
organic sulfur
 pyritic sulfur
 total  sulfur
 sulfate
 standard deviation
 absolute temperature,  K
 time,  hours (leaching)-minutes (regeneration)
 volume
 pyrite concentration in coal, wt%
 ferric ion to total iron ratio
                  82

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                        8.0  UNIT CONVERSION TABLE
  To Convert From
btu
feet (ft)
gallons (gal)
inches (in.)
miles (mi)
ounces (oz)
pounds (Ibs)
pounds (Ibs)
square miles (sq.mi)
temp (°F -32)
tons
calories (cal)
meters (m)
liters
centimeters  (cm)
kilometers (km)
grams (g)
grams (g)
kilograms (kg)
square kilometers (sq.km)
temp  (°C)
kilograms (kg)
Multiply By
 252.0
   0.3048
   3.785
   2.540
   1.609
  28.35
 453.6
   0.4536
   2.590
   0.5556
 907.200
                                    83

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                              9.0  APPENDICES
                             TABLE OF CONTENTS
APPENDIX A   Seam Extent and Sample Location	
APPENDIX B   Ranking of Treated and Untreated Coals 	
APPENDIX C   Untreated Coal Analysis Data 	
APPENDIX D   Pyritic Sulfur Removal Data	
APPENDIX E   Washability Tables 	
APPENDIX F   Methods Development and Trace Element Analysis Data.
             References for Appendix F	
P_age_
 90
134
142
148
155
176
203
                                     84

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                                APPENDICES

                                  TABLES
                                                                      Page
A-l to A-2    Sulfur Content Data

   A-l          Average Sulfur Content of U.S. Coal                      91
   A-2          Average Sulfur Content of Coals by State                 94

B-l to B-5    Coal Ranking Data

   B-l          Untreated Coal, Final Twenty Coals                     135
   B-2          Untreated Coal, Initial Fifteen Coals                  136
   B-3          Pyritic Sulfur Extractions, Final  Twenty  Coals          137
   B-4          Pyritic Sulfur Extractions, Initial  Fifteen  Coals       138
   B-5          Computer Program for Determining the Rank of Coal       139

C-l to C-5    Untreated Coal Analyses

   C-l          Muskingum, Powhattan No. 4, Isabella and                143
                Mathies Mines
   C-2          Williams, Robinson Run, Shoemaker and Delmont          144
                Mines
   C-3          Marion, Lucas, Bird No. 3, and Martinka Mines          145
   C-4          Meigs, Dean, Kopperston No. 2 and Harris  Nos.  1         146
                and 2 Mines
   C-5          North River, Homestead, Ken and Star Mines             147

D-l to D-5    Pyritic Sulfur Removal Data

   D-l          Muskingum, Powhattan No. 4, Isabella and                149
                Mathies Mines
   D-2          Williams, Robinson Run, Shoemaker and Delmont          150
                Mines
   D-3          Marion, Lucas, Bird No. 3, and Martinka Mines          151
   D-4          Meigs, Dean, Kopperston no. 2 and Harris  Nos. 1         152
                and 2 Mines
   D-5          North River, Homestead, Ken, and Star Mines             153
   D-6          Pyritic Sulfur Removal Data

E-l to E-60   Washability Tables

                Muskingum Mine

   E-l          38.1 mm x 149y  (1-1/2"x  100 mesh)                     156
   E-2          9.51 mm x 149u (3/8" x 100 mesh)                       156
   E-3          1.41 mm x 0  (14 mesh x 0)                              156

                Powhattan No. 4 Mine

   E-4          38.1 mm x 149y (1-1/2" x  100 mesh)                     157
   E-5          9.51 mm x 149n (3/8" x 100 mesh)                       157
   E-6          1.41 mm x 0  (14 mesh x 0)                              157

                Isabella Mine

   £-7          38.1 mm x 149u (1-1/2" x  100 mesh)                     158
   E-8          9.51 mm x 149u (3/8" x 100 mesh)                       158
   E-9          1.41 mm x 0  (14 mesh x 0)                              158


                                    85

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             Mathies Mine

E-10         38.1 mm x 149y (1-1/2" x 100 mesh)                     159
E-ll         9.51 mm x 149y (3/8" x 100 mesh)                       15g
E-12         1.41 mm x 0 (14 mesh x 0)                              159

             Williams Mine
E-13         38.1 mm x 149y (1-1/2" x 100 mesh)                     160
E-14         9.51 mm x 149y (3/8" x 100 mesh)                       160
E-15         1.41 im x 0 (14 mesh x 0)                              160

             Robinson Run Mine

E-16         38.1 mm x 149y (1-1/2" x 100 mesh)                     161
E-17         9.51 mm x 149y (3/8" x 100 mesh)                       161
E-18         1.41 mm x 0 (14 mesh x 0}                              161

             Shoemaker Mine

E-19         38.1 mm x 149y (1-1/2" x 100 mesh)                     162
E-20         9.51 mm x 149y (3/8" x 100 mesh)                       162
E-21         1.41 rrni x 0 (14 mesh x 0)                              162

             Delmont Mine

E-22         38.1 mm x 149y (1-1/2" x 100 mesh)                     163
E-23         9.51 mm x 149y (3/8" x 100 mesh)                       163
E-24         1.41 mm x 0 (14 mesh x 0)                              163

             Marion Mine
E-25         38.1 mm x 149y (1-1/2" x 100 mesh)                     164
E-26         9.51 mm x 149y (3/8" x 100 mesh)                       164
E-27         1.41 mm x 0 (14 mesh x 0)                              164

             Lucas Mine
E-28         38.1 mm x 149y (1-1/2" x 100 mesh)                     165
E-29         9.51 mm x 149u (3/8" x 100 mesh)                       165
E-30         1.41 mm x 0 (14 mesh x 0)                              165

             Bird No. 3 Mine

E-31         38.1 mm x 149y (1-1/2" x 100 mesh)                     166
E-32         9.51 mm x 149y (3/8" x 100 mesh)                       166
E-33         1.41 mm x 0 (14 mesh x 0)                              166

             Martinka Mine

E-34         38.1 mm x 149y (1-1/2" x 100 mesh)                     167
E-35         9.51 mm x 149y (3/8" x 100 mesh)                       167
E-36         1.41 mm x 0 (14 mesh x 0)                              167
                                 ftfi

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                Meigs Mine
   E-37         38.1 mm x 149y (1-1/2" x 100 mesh)                     168
   E-38         9.51 mm x 149y (3/8" x 100 mesh)                      168
   E-39         1.41 mm x 0 (14'mesh x 0)                             168

                Dean Mine
   E-40         38.1 mm x 149y (1-1/2" x 100 mesh)                     169
   E-41         9.51 mm x 149y (3/8" x 100 mesh)                      169
   E-42         1.41 mm x 0 (14 mesh x 0)                             169

                Kopperston No. 2 Mine
   E-43         38.1 mm x 149y (1-1/2" x 100 mesh)                     170
   E-44         9.51 mm x 149y (3/8"  x 100 mesh)                      170
   E-45         1.41 mm x 0 (14 mesh x 0)                             170

                Harris Nos. 1 & 2 Mines
   E-46         38.1 mm x 149y (1-1/2" x 100 mesh)                    171
   E-47         9.51 mm x 149u (3/8"  x 100 mesh)                      171
   E-48         1.41 mm x 0 (14 mesh  x 0)                             171

                North  River Mine
   E-49         38.1 mm x 149y (1-1/2" x 100 mesh)                     172
   E-50         9.51 mm x 149y (3/8"  x 100 mesh)                       172
   E-51         1.41 mm x 0  (14 mesh  x 0)                              172

                Homestead Mine
   E-52         38.1 mm x 149y  (1-1/2" x 100 mesh)                     173
   E-53         9.51 mm x 149y (3/8"  x 100 niesh)                       173
   E-54         1.41 mm x 0  (14 mesh  x 0)                              173

                Ken Mine
   E-55         38.1 mm x  149y  (1-1/2" x 100 mesh)                     174
   E-56         9.51 mm x  149y  (3/8"  x  100  mesh)                       174
   E-57         1.41 mm x 0  (14 mesh  x 0)                              174

                Star Mine
   E-58         38.1 mm  x  149y  (1-1/2"  x 100 mesh)                     175
   E-59         9.51 mm  x  149y  (3/8"  x  100  mesh)                       175
   E-60          1.41 mm  x  0 (14 mesh  x  0)                              175

F-l            Atomic Absorption  Analytical  Parameters                 -j82

F-2 to F-ll    Trace Element Analyses  Data
   F-2         Muskingum Mine                                        193
   F-3         Mathies Mine                                          194
   F-4          Robinson Run Mine                                     195
    F-5          Powhattan No. 4 Mine                                  196
    F-6          Delmont Mine                                          197
    F-7          Marion Mine                                           198
    F-8          Lucas Mine                                             199
    F-9          Bird No.  3 Mine                                       200
    F-10         Meigs Mine                                            201
    F-ll          Ken Mine                                              202

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                               APPENDICES
                                 FIGURES
                                                                      Page
                 Maps - Seam Extent and Sample  Location
A-l  Percentage Distribution of Cumulative  Coal Production of the        92
     United States to 1 January 1967
A-2  Coal Fields of the Conterminous United States                       92
A-3  Coal Resources of the United States                                 93
A-4  Pennsylvania - Sewickley Seam                                     105
A-5  West Virginia - Sewickley Seam                                    106
A-6  Ohio - Sewickley Seam                                             107
A-7  Pennsylvania - Pittsburgh Seam                                    108
A-8  West Virginia - Pittsburgh Seam                                   109
A-9  Ohio - Pittsburgh Seam                                            110
A-10 Pennsylvania - Upper Freeport (No. 7)  Seam                        111
A-11 West Virginia - Upper Freeport (No. 7)  Seam                        112
A-12 Ohio - Upper Freeport (Ho.  7)  Seam                                 113
A-13 Pennsylvania - Lower Freeport (No. 6A)  Seam                        114
A-14 West Virginia - Lower Freeport (No.  6A) Seam                      115
A-15 Ohio - Lower Freeport (No. 6A) Seam                                116
A-16 Pennsylvania - Upper Kittanning Seam                              117
A-17 West Virginia - Upper Kittanning Seam                             118
A-18 Ohio - Upper Kittanning Seam                                      119
A-19 Pennsylvania - Middle Kittanning (No.  6) Seam                     12°
A-20 West Virginia - Middle Kittanning (No.  6)  Seam                    121
A-21 Ohio - Middle Kittanning Seam                                     I22
A-22 Pennsylvania - Lower Kittanning Seam                              I23
A-23 West Virginia - Lower Kittanning Seam                             124
A-24 Ohio - Lower Kittanning Seam                                      I25
A-25 Ohio - Clarion 4A Seam                                            126
A-26 Eastern Kentucky - Mason Seam                                     I2?
A-27 Illinois - No. 5 - Harrisburg-Springfield Seam                    128
A-28 Indiana - Springfield - No. V Seam                                 129
                                    88

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A-29  Western  Kentucky -  No.  9  Seam                                    130
A-30  Illinois -  Herrin No. 6 Seam                                     131
A-31  Western  Kentucky -  No.  11  Seam                                   132
A-32  Indiana  - Hymera No.  VI Seam                                     133
                                     89

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          APPENDIX  A
SEAM EXTENT AND SAMPLE LOCATION
                90

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A.I  Selection of Coals

     Some of  the background  information which was utilized to aid in the

selection of  the twenty  coals  for  this study is presented below in three

paragraphs:   Previous  Production by State, Distribution of Coal Reserves

and Distribution of Sulfur Content(4»5)-
          Previous  Production by State  -  Figure A-l shows the percentage
          distribution  of the cumulative  production of coal in the United
          States  up to  January 1, 1967.   In  descending order of production,
          the  six most  productive states  were:  Pennsylvania, West Virginia,
          Illinois, Kentucky, Ohio and  Indiana.  These states have produced
          slightly  over 84% of the coal  consumed to date.

          Distribution  of Coal Reserves in the United States - The
          distribution  of the coal reserves  in the United States is shown
          by Figure A-2, which gives aerial  distribution  and Fiqure A-3,
          which quantitatively describes the total  resources  remaining.
          From an examination of Figure A-3, it is apparent that coal from i
          the  following seven states would represent  the  vast majority of
          the  remaining resources of bituminous coal  in the United States:
          Illinois, West Virginia, Colorado, Pennsylvania, Kentucky, Ohio
          and  Indiana.
          Distribution of Sulfur Content in Coal
          general distribution
                     and average
This distribution shows that the
sulfur coal are east of the Mississippi
	 -  Table A-l  shows  the
sulfur content of U.S.  coals.
major areas containing  high
       River.
                                  TABLE A-l

                    AVERAGE SULFUR CONTENT OF U.S. COAL*
Coal Resources Determined
by Mapping and Exploration
Total bituminous coal, subbituminous
coal, and lignite
Bituminous coal east of the
Mississippi River
Low Sulfur
(1.02 or
Less)
652
20%
Medium
Sul fur
f].l-3.03rt
15%
37%
High
Sulfur
(>32H
20%
43%
*Dry basis.
                                     91

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STATES WEST
 OF THE
MISSISSIPPI
 RIVER
       WESTERN INTERIOR BASIN 3.6

 ROCKY MOUNTAIN STATES 4.4
WEST COAST AND ALASKA 0.5

       ALABAMA 2.7

    TENNESSEE 1.1

  VIRGINIA 2.6
      OTHER STATES 0.9
                                                          A 3.3
                            Figure  A-l

          Percentage  Distribution  of Cumulative  Coal
       Production  of  the  United  States  to 1 January 1967
                              Figure  A-2

         Coal  Fields of  the Conterminous United States
                                   92

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                                          Figure A-3
                       COAL RESOURCES OF THE  UNITED STATES
                                        100
                                      BILLIONS OF SHORT TONS
                                               200
300
UD
co
NORTH DAKOTA
    MONTANA
      ILLINOIS
      ALASKA ]
   WYOMING1
 WEST VIRGINIA
   COLORADO2
PENNSYLVANIA
    KENTUCKY
 NEW MEXICO2
        OHIO
      INDIANA
        UTAH
     MISSOURI
      KANSAS
     ALABAMA
        TEXAS
    VIRGINIA2


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FP»1 LIGNITE
i^ ANTHRACITE At
SEMlANTHRAd
3AL
S COAL
vID
[E
                           NOTES:
                           1  SMALL RESOURCES OF LIGNITE INCLUDED WITH SUBBITUMINOUS COAL
                           2  INCLUDES ANTHRACITE IN QUANTITIES TOO SMALL TO SHOW ON SCALE
                             OF DIAGRAM

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        A review of the  average sulfur content of the states previously

demonstrated to be  of  interest from a reserve or production point of view

are listed below in Table A-r2.

                                   TABLE A-2

                  AVERAGE SULFUR CONTENT OF COALS BY STATE*
                *Dry basis.
A. 1.1  Coal Sample Selection
State
Colorado
West Virginia
Illinois
Kentucky
Ohio
Indiana
Pennsylvania
%S
0.56
1.40
2.95
2.22
3.52
3.00
1.96
                             (4,5)
                            APPALACHIAN COALS

     Coals sampled, as noted in the following sections, are given in their

descending strati graphic order in the Monongahela, Conemaugh, and Allegheny
stratigraphic groups, as defined in Pennsylvania and correlated with other
beds of the Appalachian Region.

     t   Sewickley Seam - The Sewickley seam, most recent in geologic
         age of the coal beds investigated, is present in Pennsylvania
         (Greene, Butler, Clarion, Armstrong, Washington, Fayette,
         Westmoreland and Allegheny Counties), West Virginia (Marion,
         Monongalia, Wetzel, Marshall and Ohio Counties, where an
         estimated 2 billion tons remain), and Ohio, where the Sewickley
         correlates with the Metgs Creek (or No. 9) seam which is found
         in Monroe, Belmont, Harrison and Jefferson Counties.  The Meigs
         Creek seam ranks third in production in Ohio.  This initial
         survey initiated the examination of this coal with a sample
         from the Warwick mine in Greene County, Pennsylvania.  Sub-
         sequently, a sample of this coal was taken at the Muskigum
         mine in Morgan County, Ohio.  State maps showing the extent
         of this bed and the locations of the two mines are shown as
         Figures A-4, A-5 and A-6.
                                   94

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Pittsburgh Seam - The Pittsburgh bed has  been  described as the
most valuable individual mineral deposit  in  the  United States.
It is of minable thickness over an area of about 15,000 sq. km
(6,000 sq. mi) in Pennsylvania (Washington,  Greene,  Indiana,
Somerset, Allegheny, Armstrong, Westmoreland and Fayette Counties
where approximately 7 billion tons remain),  West Virginia  (parts
of Brooke, Ohio, Marshall, Wetzel, Monongalia, Marion, Doddridge,
Harrison, Taylor, Preston, Mineral, Barbour, Upshur, Lewis,
Gilmer, Braxton, Calhoun, Clay, Roane, Kanawha, Putnam, Mason,
Cabell and Wayne Counties with approximately 10 billion tons
of minable reserves), and eastern Ohio (primarily Belmont,
Harrison, Jefferson, Carroll, Columbiana, Mahoning and Monroe
Counties which contain  some 10 billion tons of reserve).
Pittsburgh coal is  also found in the Georgis Creek basin
(Garrett and Allegheny  Counties, Maryland) where only about
2 million tons remain.  A Pittsburgh coal from Greene County,
Pennsylvania was examined in the previous bench-scale program^1'.
This program expanded the coverage of the Pittsburgh bed  by
sampling coals from:  the Humphrey No. 7, Williams, Robinson
Run, and Shoemaker  mines  in West Virginia; the Mathies  and
Isabella mines in Pennsylvania;  and  the  Egypt Valley No.  21
andPowhattan No. 4  mines  in Ohio.  State maps showing the
counties containing minable Pittsburgh coal and the locations
of the mines sampled are  shown  in  Figures A-7,  A-8  and A-9.
In this case, where the remaining  reserves  are  rather clearly
defined, the yearly production  of  the  mines sampled represent
approximately one two-thousandths  of the seam reserve.

Upper  Freeport Seam - The Upper Freeport bed  is  less uniform
in thickness than the overlying Pittsburgh  bed  or the underlying
Lower  Kittanning bed because  it was  subjected to  local uplift
and  erosion  before  deposition  of the overlying  rocks.  Neverthe-
less,  it  is  a persistent bed  throughout  large areas in Pennsylvania,
West Virginia,  and  Ohio, and  is the third most important  bed in
the  northern  part of  the Appalachian bituminous coal basin, both
in production and in  contained resources.   In Pennsylvania, the
Upper Freeport  bed  is  thick and continuous in the counties around
Pittsburgh  and  in  the  southwestern part  of the state, where  it
ranges in  thickness from 0.6 to 3 m (2 to 10 ft), and is  1 to  2 m
(4 to 6  ft)  thick  over considerable areas.   In West Virginia,  the
Upper Freeport  bed  is  considered to be of minable thickness  and
purity over an  area of 3,030 sq. km (1,165 sq.  mi) in a  belt
running north-south through the central  part of the state.   In
the  northern part  of the belt it ranges  in thickness from 0.9  to
4 m  (3 to 12 ft)  and is 1 to 1.5 m (4 to 5 ft) thick over large
areas.  It thins to the south and is generally less than 0.6 m
(2  ft) thick in Clay and Braxton Counties.  In Ohio, the Upper
Freeport bed is  very irregular in thickness.  It is locally  as
much as 2 m (8 ft)  thick, but typically thins within a  few  miles,
or  tens  of miles,  to less than 35 cm (14 in.).  Nevertheless,  its
wide distribution makes it the fourth most important bed in  Ohio
in  known resources.  The Marion and Delmont mines  in Westmoreland
                           95

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 and Indiana Counties in Pennsylvania were  sampled.   State maps
 showing the location of these mines and the  counties containing
 minable coal are shown in Figures A-10, A-11  and A-12.

 Lower Freeport (No.  6A) Seam -  The Lower Freeport seam is also
 present in Pennsylvania,  West Virginia, Ohio  and Maryland.  In
 Pennsylvania it is  present  in Lawrence, Beaver,  Washington,
 Greene, Butler, Allegheny,  Fayette,  Westmoreland, Armstrong,
 Indiana, Somerset,  Cambria,  Bedford and Fulton Counties.  In
 teest Virginia, it is minable in parts  of Nicholas, Roane,
 Braxton, Preston, Ohio, Brooke  and Hancock Counties.  Of the
 original 700 million tons minable in West  Virginia,  compara-
 tively little has been removed.   In  Ohio the  Lower Freeport
 is present and of importance in Jefferson, Athens, and Perry
 Counties where some  3 billion tons remain.   In Maryland the
 Lower Freeport is mined in  Garrett and Allegheny Counties in
 the northwest corner of the  state bordering  on West  Virginia
 and Pennsylvania.  For this  program, a sample was taken from
 the Jane Mine in Pennsylvania.   State  maps showing the counties
 with minable Lower  Freeport  coal  as  well as  the  location of
 the mine sampled are shown  in Figures  A-13,  A-14 and A-15.
 Since  only two counties in  Maryland  are of concern,  they are
 not mapped.

 Upper Kittanning Seam - The  Upper Kittanning  coal is strati-
 graphical ly  the  uppermost of  the  three  Kittanning coals originally
 named  at Kittanning,  Pennsylvania.   In  Pennsylvania  {Lawrence,
 Beaver, Washington,  Greene,  Fayette, Westmoreland, Armstrong,
 Clarion, Jefferson,  Indiana,  Somerset,  Cambria and Clearfield
 Counties)  the  seam is  thin and  thus  infrequently deep-mined.  In
 West Virginia,  the coal is of sufficient thickness for mining
 in  parts of  Kanawha,  Nicholas,  Clay, Braxton, Webster, Upshur,
 Lewis,  Randoph,  Barbour, Harrison, Taylor, Marion, Monongalia and
 Preston  Counties  over an  area of  some  3,600 sq.  km (1400 sq. mi).
 The original  reserves  in West Virginia  were estimated at 4
 billion  tons;  and since this  bed  has not been a  major producer
 for the  state,  the majority  of  the coal  remains.

The Upper  Kittanning seam is  not a major coal bed in Ohio but geo-
logically it follows the Lower Kittanning in  its persistence from
northeast to southwest in the Ohio coal fields.  In Maryland, the
Upper Kittanning seam is mined in both Garrett and Allegany
Counties where it forms parts of the 1 billion tons  of remaining
coal reserves.

 One sample for this  program  was  taken  from the Walker Mine  in
 Maryland.  State  maps  showing the extent of this bed are shown
 in  Figures A-16,  A-17, and A-18.   (Maryland, where the sample
 was taken, is  again  not shown because  of the  two county repre-
 sentations.)
                           Qfi

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Middle Kittanninq or No.  6 Seam  -  This  bed of coal is remarkably
uniform and persistent and for many years was the most important
coal bed in Ohio from the standpoint  of quality and production.
It is now outranked in production  by  the Pittsburgh (No. 8) bed,
but is mined in every county along its  outcrop from the Ohio-
Pennsylvania state line and in Columbiana County on the north
to Lawrence County on the south.  This  great  coal bed is also
important in Pennsylvania and West Virginia,  and  is  tentatively
correlated with the important Herrin  (No. 6)  coal of Illinois.
Conservative estimates indicate well  over 7 billion tons of No.
6 coal is over 0.9 m  (28 in.) thick in Ohio.

The coal is exceptionally firm and stands  shipping well which,
coupled with low ash  often having high fusion temperature  and  a
very low "free swelling index" (free  burning), makes  it  an
exceptional coal for  the retail  market.  When it  is mechanically
cleaned and sized, it is an outstanding domestic  stoker coal,
free from troublesome "coke trees" and other operating  difficulties.
It is extensively used in the ceramic and cement  industries owing
to its superior performance under difficult operating  conditions.
For steam generation, it gives unusually good performance  on
chain or traveling grate stokers.  Owing to its  favorable  ash
softening  temperature and burning characteristics it performs
well in both multiple and single  retort underfeed stokers.

A single sample from  this seam was taken from the Lucas Mine  in
Columbiana County, Ohio.  State maps showing the location  of
this mine and the extent of the same are shown in Figures  A-19,
A-20, and A-21.

Lower Kittanning Seam - The Lower Kittanning bed is most pervasive
throughout the northern part of the Appalachian basin throughout
portions of Pennsylvania, West  Virginia, Ohio and Maryland.   In
Pennsylvania (Lawrence, Beaver, Washington, Greene, Fayette,
Westmoreland, Butler, Clarion,  Armstrong, Somerset, Indiana,
Jefferson, Clearfield, Cambria, Bedford and Fulton Counties)  it
is widely strip mined.   In West Virginia the Lower Kittanning
(also called the No.5 Block)  is minable in parts of Mingo, Logan,
Boone, Wayne, Lincoln, Kanawha, Nicholas, Fayette, Clay,  Roane,
Braxton, Webster, Randolph, Upshur,  Lewis, Barbour, Taylor, Marion,
Mononqalia, Preston and  Mineral Counties.  It covers an area
greater than 6,700 sq. km (2600 sq.  mi) and  is estimated to have
originally contained  over  10  billion tons.  Though one of the
most mined beds  of West  Virginia, much of this reserve remains.
This coal  is present  in  most  of the  counties comprising the coal
fields  of eastern Ohio,  extending from Mahoning County in the
northeast  through Lawrence  and  Scioto  Counties in the southeast.
In  Ohio, the estimated minable  reserves total three billion tons.
The  coal is  also  present in  the two  coal counties of Maryland
(unmapped),  though  this  is  not  of major commercial importance.
                            97

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The previous bench scale progranr    examined  a  Lower Kittanning
coal from Indiana County, Pennsylvania.   For  this  program,
samples were obtained from the Fox and Bird No.  3  mines  in
Pennsylvania and the Martinka mine in West Virginia.   State
maps showing the extent of this bed and the mine locations are
given in Figures A-22, A-23,  and A-24.

Clarion or No.  4A Seam - The  Clarion coal  can be traced  from  the
Ohio-Pennsylvania line southwest to the Ohio  River.   However,
along most of this line of outcrop the bed is too  thin to be
worked.  The one deposit of importance lies  in  the southern
part of the state and includes northern Lawrence,  eastern Scioto,
eastern Jackson, northwestern Gallia, and southern Vinton
Counties.  In places the coal lies directly below  the Vanport
lime but elsewhere is separated by two partings of clay.  This
varies, however, and especially so along the  margin of the  field.
The thickness of the bed in Southern Ohio is  10.9  to 1.2 m
(3 to 4 ft) thick.  The Clarion coal is moderate in heating
value, high in sulfur and ash.

Clarion coal when washed is a very suitable  industrial coal  for
steam generation utilizing underfed stokers,  pulverized  fuel
furnaces, chain or traveling grate stokers,  and spreader stokers.
The most desirable feature of this coal for  steam use is the
wide  ash fusion range, as the fusion starts  at an initial  2150°F,
with the softening temperature 2280°F and the ash  fluid temper-
ature at 2560°F.  This fusion range makes it a  relatively safe
coal to use on stokers.

A sample from this seam was taken  from the Meigs mine in Meigs
County, Ohio.  A state map showing the location of this  mine  is
shown in Figure A-25.

Dean Seam - The Dean seam, more commonly known  as Big Mary seam,
has its most important development in the New River area of
Anderson, Campbell, and Morgan Counties in Tennessee.  Mining
thicknesses in this area range from 0.9 to 3 m (36 in. to 10 ft)
or more.  The roof is a strong gray shale unusually subject to
air slacking, while the bottom is  a soft shale or clay.   The
Big Mary seam commonly occurs in  two  benches; and in  the thinner
seam areas, only the upper bench  is evident.   The lower bench
may vary from 0.2 to 0.7 m (10 in. to 30 in.) in thickness and
occurs below the top bench with an interval  of from several
inches to 1.5 m (5 ft) or more.   Occasionally, the two benches
join to form a thick seam.  The coal  from the Big Mary vein is
coarse and blocky.  It is suitable for general  steam  and domestic
use and was formerly a favorite railroad fuel.   A single sample
was taken from the Dean mine in Scott County, Tennessee.
                           98

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 Mason  Seam -  To  provide an example of an Eastern Kentucky  coal,
 a  sample was  taken  from the Dixie Fuel Company's No.  1  mine  in
 Harlan County, Kentucky.  A state map showing the location of
 the  sampling  point  in  the Upper Cumberland reserve district  is
 shown  in Figure  A-26.

 Campbel1 Creek Seam -  A domestic steam, gas, by-product, and
 metallurgical coal  named for  its occurrence along Campbell Creek,
 Kanawha County,  West Virginia.  It is minable in parts  of Wayne,
 Mingo, Wyoming,  McDowell, Logan, Lincoln, Boone, Raleigh,  Fayette,
 Kanawha, Nicholas,  Clay, and  Calhoun  Counties in West Virginia
 over an area  of  about  5,400 sq. km (2,100 sq. mi); it is the
 most important seam of the entire Pottsville Group, the original
 minable tonnage  estimated as  having been about  8 billion tons.
 The  coal is generally  a multiple-bedded gas and splint type coal;
 it is  0.6  to  3 m (2 to 10 ft)  thick,  averaging  perhaps 1.5 m
 (5 ft).  It occurs  11  to 29 m (37 to  95 ft) above the Powellton
 coal.   A sample  of  this seam  was taken from the Kopperston No. 2
 mine in Wyoming  County, West  Virginia.

 Eagle  Coal  Seam  - A domestic  steam, by-product  and coking coal
 named  for  Eagle, West  Virginia, where it was first mined.  It
 is minable in parts of McDowell, Mingo, Wyoming, Boone, Kaleigh,
 Kanawha, Fayette, Nicholas, Clay, Webster, Braxton, Upshur, and
 Randolph Counties in West Virginia over an area of 3,500  sq. km
(1,360  sq.  mi); the  original minable tonnage is  estimated  to have
 been nearly 4.2  billion  tons.  The coal is double-to-multiple-
 bedded and splinty  and ranges from 0.6 to 3 m  (2 to 10  ft) thick,
 averaging  perhaps  1.2  m  (4  ft).  A sample of this bed was taken
 from the Harris  Nos. 1 and  2  mines in Boone County, West  Virginia.

 Corona Seam - In Alabama  the  Pratt Coal Group  ranks second only
 to the Mary Lee  Group  from  a  tonnage  standpoint and includes  the
 American  (Nickel Plate),  Curry,  Gillespie and  Pratt  (Corona).
 beds mined in Jefferson  and Walker Counties.   The principal
 beds in this  group  are the  Pratt (known in  the western  part  of
 the basin  as  the Nickel  Plate).  Thickness  of  the Pratt bed
 varies from 0.9  to  1.7 m (2 ft 10  in. to  5-1/2 ft);  an  average
 of 26  sections  of  this bed  shows  1.7  m  (5-1/2  in.) of  coal,
 63 cm  12-1/2  in.)  of parting  and 0.9  m  (34  in.) of coal.   Roof
 and floor  of the Pratt bed  usually  are  sandstone.  This bed is
 one of the major sources  of coking  coal in  Alabama.  The  Corona,
 which  ranges  from 0.8 to 1.2  m (30  to 52  in.)  in thickness,
 probably  is the  western  extension  of  the  Pratt bed.  A single
 sample was taken from the  North  River mine  in  Jefferson County,
 Alabama.
                          99

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               EASTERN INTERIOR REGION

 No.  5 Bed (I11J, or No. 9 ^Ky.) Seam - The No. 5 bed is the
 most widespread  and commercially valuable coal bed in the
 Eastern  Interior coal basin.   It is known in Illinois as the
 No.  5 Harrisburg or Springfield bed;  in  Indiana  as  the  Spring-
 field or No. V bed; and in western Kentucky as the No. 9 bed.
 It is of minable thickness over an area of about 52,000 sq.  km
 (20,000  sq. mi)  in the three states and it is recognizable
 as a lithologic  unit over an area of about 78,000 sq. km
 (30,000  sq. mi).  In southeastern Illinois, it is 1 to 1.5 m
 (4 to 5  ft) thick over large areas; in Indiana it has an
 average  thickness of 1.5 m (5 ft) and locally is as much as
 3  m  (11  ft) thick throughout its area of occurrence.  From
 the  standpoint of resources,  it is the most important bed in
 Indiana  and western Kentucky, and it is second only to the
 Herrin No. 6 bed in Illinois.

 In Illinois the No.  5 bed is  present in strippable quantities  in
 some  fifty counties  having more than forty-one billion tons  of
 reserves.  In Indiana,the Springfield (No.  V) bed is present in
 Sullivan, Vigo, Knox, Greene, Daviess, Pike, Gibson, Posey,
 Vanderburgh and Warrick Counties, which contain twenty-six
 billion tons of reserve.

The correlating coal  seam in  western Kentucky (the No. 9 bed)
 is commonly found throughout  the entire reserve district and
presently may be mined in Butler, Daviess,  Henderson, Hopkins,
Muhlenberg, Ohio, Union,  or Webster Counties.

A previous prograrrr  ' utilized a No. 5 coal from Fulton
County, Illinois.  This  survey program has  obtained samples
from the Eagle No.  2  mine in  Gal latin County, Illinois.   In
Kentucky, samples were taken  from the Camp  Nos. 1 and 2 mines
in Union County, the  Ken mine in Ohio County and the Star mine
in Hopkins County.   State maps showing the  extent of these beds
are shown in Figures  A-27, A-28,  and A-29.

Herrin No. 6 Bed (IllJ,  No. 11 (Ky.) Seam - The Herrin No. 6
bed is recognizable  over an area of about 29,000 sq. km (15,000
sq. mi) in the Eastern Interior coal basin, where it is second
in commercial importance only to the No.  5  bed.  It is known in
western Kentucky as  the No. 11 bed and in Indiana as the Hymera
or No. VI bed.   This  coal attains maximum thickness in southern
Illinois, where it is locally as much as  4 m (14 ft) thick.   In
central Illinois and in western Kentucky, the Herrin (No. 6) bed
is 1.5 to 2 m (5 to  7 ft) thick over large  areas.  It thins
eastward and is relatelv unimportant in Indiana.  It also thins
toward the northwest  edge of  the  basin.  From the standpoint
of resources and production,  it is the most important coal in
 Illinois.  In Illinois,  the No. 6 bed has reserves in fifty-six
counties, totalling  approximately sixty-six billion tons.
 In Kentucky, the No.  11  bed is presently being
                        100

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mined in Hopkins, Ohio and Muhlenberg  Counties.   Indiana's
equivalent Hymera (No. VI) bed is  of lesser  importance but
it occurs in minable thickness in  Sullivan,  Knox, Pike, Gibson,
Warrick, Vanderburgh and Posey Counties.

The previous bench-scale prograrrr  ' utilized a  No. 6 coal from
Randolph County, Illinois and the  present program examined
samples of No. 6 coal from the Orient  No.  6  mine  in Jefferson
County, Illinois and from the Homestead mine in Ohio County,
Kentucky.  State maps showing the  extent of  minable beds  and
the mine locations are shown in Figures A-30, A-31, and A-32.
               WESTERN INTERIOR REGION

 Des Moines No. 1 Seam - To provide a sample of coal from the Western
 Interior Region, an Iowa coal from Marion County (the Des  Moines
 No. 1) seam was selected.  Iowa's total reserves are an estimated
 7 billion tons.
                  WESTERN COAL REGION
Wadge Seam - The Wadge seam of the Yampa field in the Green River
region is an example of coals from the northwestern part of
Colorado.  The Edna mine in Routt County was sampled.  The Wadge
seam in Colorado correlates with other coals of the Green River
region mined in the Rock Springs area in southwestern Wyoming.
In Colorado, the reserves are estimated at some one and one-half
billion tons.

No. 6, 7 and 8 Seams (Fruitland Formation) - The No. 6, 7 and 8
seams of the Fruitland Formation are presently being mined by
one of the largest stripping operations in the nation at the
Navajo mine in San Juan County, New Mexico.  The coal resources
of New Mexico are estimated at 62 billion tons, 80% of which are
 subbituminous  coals  which  include  the  coal  mined at the  Navajo
 mi ne.

Roland-Smith Seam -  The Roland-Smith seam of the Powder  River
Region represents one of the largest strippable  reserve  areas
of subbituminous coal in the U.S.  For this program a sample
of the seam was taken from  the Belle Ayr mine  in Campbell  County
(center of the  Powder River Region), Wyoming.

Rosebud Seam -  The  Rosebud seam of subbituminous coal  is repre-
sentative of the  vast reserves  (20 billion  tons)  of strippable
coal  available  in the Fort  Union Region of  Eastern Montana.   This
 region  is represented in  northeastern  Wyoming  by the coals of the
Powder  River Region  and  translates  into the lignites of eastern
Montana  and western  North  Dakota.   For the  survey program, a sample
was  taken  from a  large mine in the  area,  the Col strip  mine in
 Rosebud  County,  Montana.
                          101

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A.1.2  Mine Sample Procedures

     The following tabulation describes  in  detail  the  specific sampling
procedures used in the twenty additional  mines  sampled in  this part of
the program.  The procedures for the initial  fifteen coals were documented
          (3)
previously   .
       •  Muskingum Mine, Meigs Creek No. 9 Seam,  Morgan  County,  Ohio,
          Central Ohio Coal  Company.  The raw run  of the mine coal was
          collected over a 4 hour period  on September  17,  1973.   One
          hundred and forty-four increments totaling 908 kg  (2000 Ibs)
          were taken by stopped belt sampling as the coal  was going to
          the preparation plant.

       t  Powhattan No. 4 Mine, Pittsburgh  No.  8 Seam, Monroe County, Ohio,
          Quarto Mining Company., The raw  run of the mine  coal sample was
          collected over a 3-3/4 hour period of September  18, 1973.  One
          hundred and forty-eight increments  totaling  908  kg (2000 Ibs) were
          taken from a stopped belt leading from the stock pile  to the
          tipple.

       •  Isabella Mine, Pittsburgh Seam, Fayette  County.  Pennsylvania,
          National Mines Corporation.  The raw  run of  mine sample was
          collected over a 3-1/2 hour period on November 21, 1973.
          One hundred and forty-eight increments totaling  908 kg  (2000 Ibs)
          were taken from a stopped belt leading  from  the mine  to the
          preparation plant.

       t  Mathies Mine, Pittsburgh Seam. Washington County, Pennsylvania,
          Mathies Coal Company. The  raw  run  of mine sample  was
          collected over a 4 hour period on July 23,   1973.  Ninety
          increments totaling 908 kg  (2000 Ibs) were   taken  from a stopped
          belt leading from the mine  to  the coal  preparation plant.

       t  Robinson Run Mine, Pittsburgh  Seam, Harrison County,  West
          Virginia, Consolidation Coal Company.  The  raw run of the mine
          coal sample was collected over a 4 hour period on
          September 19,  1973.   One  hundred  and forty-four increments totaling
          908 kg  (2000 Ibs) were taken from a stopped belt  leading to the
          preparation  plant.

       •  Williams Mine. Pittsburgh  Seam,  Marion  County, West Virginia,
          Consolidated Coal  Company,  Mountaineer  Coal Company Division.
          The raw  run  of mine  coal  sample  was  collected over a 6-3/4
          hour period  on September  20, 1973.   Sixty-six 30  Ib increments
          totaling 908 kg  (2000 Ibs)  were  taken from  a stopped belt
          leading  to  the  preparation  plant.

       •  Shoemaker  Mine,  Pittsburgh Seam, Marshall County, West Virginia,
          Consolidation  Coal  Company, Mountaineer Coal  Company  Division.
          The  raw run  of mine sample was collected over a 4 hour period
          on September 19,  1973.   One hundred  and forty-eight increments
           totaling 908 kg (2000 Ibs)  were taken from  a stopped  belt
           leading from the mine to the  preparation plant.
                                    102

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Marion Mine, Upper Freeport Seam, Indiana County,  Pennsylvania.
Tunnel ton Mining Company.  The raw run of mine coal  was  collected
over a 4-1/2 hour period on July 23, 1973,  Sixty  increments
totaling 908 kg (2000 Ibs) were taken by stopped belt sampling
as the coal was going into the silo.

Delmont Mine, Upper Freeport Seam, Westmoreland County,
Pennsylvania, Eastern Associated Coal Corporation.  The  raw run
of mine coal sample was collected over a 5 hour period on
September 21, 1973.  One hundred and sixty increments totaling
908 kg (2000 Ibs) were taken from a stopped belt leading to
the preparation plant.

Lucas Mine, Middle Kittanning Seam, Columbiana County, Ohio,
Buckeye Coal Mining Company.  The raw run of mine  sample was
collected over a 5 hour period on July 24, 1973.  Sixty
increments totaling 908 kg (2000 Ibs) were collected from
fifteen locations in the raw coal pit.

Martinka Mine, Lower Kittanning Seam, Logan County,  West
Virginia, American Electric Power Company"!  The raw  run  of
mine sample was taken during a 3-1/2 hour period on  May  2, 1974.
One hundred and forty-seven increments totaling 908  kg
(2000 Ibs) were taken from a stopped belt.

Bird No. 3 Mine, Lower Kittanning Seam, Somerset County,
Pennsylvania, Island Creek Coal Company.  The raw  run of mine
sample was taken over a 3-1/2 hour period on September 21, 1973.
One hundred and sixty-six Increments totaling 908 kg (2000 Ibs)
were taken from a stopped belt leading to the tipple and
before the coal from the No. 2 and No. 3 mines were  blended.

Meng«L Mine,  Clarion 4A Seam,  Meigs  County,  Ohio, American
Electric Power Company.  The raw run of mine sample  was
collected over a 3-1/2 hour period on September 17,  1973.   One
hundred and forty increments totaling 908 kg (2000 Ibs)  were
taken from a stopped belt leading to the stockpile.
Dean Mine, Dean Seam, Scott County, Tennessee, Royal Dean Coal
Company.  The raw run of mine sample was collected over  a
4 hour period on January 17, 1974.  Approximately 55 increments
totaling 908 kg (2000 Ibs) were taken from a stopped belt
leading from the mine to the stockpile.

Kopperston No. 2 Mine, Campbell Creek Seam, Wyoming County,
West Virginia, Eastern Associated Coal Corporation.The raw
run of mine sample was collected over a 4 hour period on
November 26, 1973.  One hundred sixty increments totaling
908 kg (2000 Ibs) were taken from a moving belt leading from
the mine to the preparation plant.
                         103

-------
0  Harris Nos. 1 and 2 Mines, Eagle and No. 2 Gas Seams, Poone
   County, West Virginia. Eastern Associated Coal Corporation.
   The raw run of mine sample was collected over a 4 hour
   period on November 26, 1973.  One hundred and forty increments
   totaling 908 kg (2000 Ibs) were taken from mine cars coming
   directly from the mine.

t  North River Mine, Corona Seam. Jefferson County,  Alabama.
   Republic Steel  Corporation.   The raw run of mine  sample was
   taken on May 23,  1974.   Fifty 40 Ib increments totaling
   908 kg (2000 Ibs) were taken from various locations in the
   stockpile.
•  Homestead Mine, No. 11 Seam. Ohio County. Kentucky. Peabody
   Coal Company.The raw run of mine sample was collected over
   a 4 hour period on December 11, 1973.  An automatic sampler was
   used to take 30 increments totaling 908 kg (2000 Ibs).

•  Ken Mine, No. 9 Seam. Ohio County, Kentucky, Peabody Coal
   Company.  The raw run of mine sample was collected over a
   4-1/4 hour period on December 12, 1973.  An automatic sampler
   was used to take  30 increments totaling 908 kg (2000 Ibs).

•  Star Mine.  No.  9  Seam. Hopkins County, Kentucky.  Peabody Coal
   Company.The raw run of mine sample was collected over a
   4 hour period on  December 13, 1973.  Approximately 30 increments
   totaling 908 kg  (2000 Ibs) were taken at the primary cut of an
   automatic sampler.
                            104

-------
                   ERIE
               CRAWFORD'
                                           WARREN
O
cn
           MERCER
                                             FOREST
                                                                  MC KEAN
                                                                                         POTTER
                                                                 ELK
                                                                               CAMERON
                            VENANGQ
                                                                                               CLINTON
       LAWRENCE
        BEAVER
'
    BUTLER
                                       CLARION
                                                    JEFFERSON
                  ARMSTRONG
                                                                     CLEARFIELD
                                                                                             CENTRE
                                                  INDIANA
                   ALLESHENY
                                                              CAMBRIA  /    BLAIR
                                                                                    HUNTINGDON
                                    WESTMORELAND
     ARV/ICK
          WASrilN
                                                     SOMERSET
                               FAVETTE
                                                                       BEDFORD
                                                                                    FULTON  /     FRANKLIN
                                                                                                               TIOGA
                                                                                                                                       BRADFORD
                                                                                                                                                             SUSQUEHANNA
                                                                                                                                                                                 WAYNE
                                                                                                                                        SULLIVAN
                                                                                                                     LYCOMING
                                                                                                                                                        WYOMING
                                                                                                                                                          LUZERNE
                                                                                                                                                                   LACKAWANNA
                                                                                                                                                                                          PIKE
                                                                                                                                           COLUMBIA
                                                                                                                        UNION
                                                                                                                                                                   CARBON
                                                                                                                                                                                MONROE
                                                                                                                                                          NORTHAMPTON
                                                                                                                                                 5CHUYLKILL
                                                                                                                                                                        LEHIGH
                                                                                                                 PERRY
                                                                                                             CUMBERLAND
                                                                                                                  ADAMS
                                                                                                                               DAUPHIN
                                                                                                                                                              BERKS
                                                                                                                                            LEBANON
                                                                                                                                                                                         BUCKS
                                                                                                                                                  LANCASTER
                                                                                                                                                                   CHESTER
                                                                                                                                                                               MONTGOMERY
                                                                                                                                                                               DELAWARE
                                                                                                                  YORK
                                                                                               PENNSYLVANIA

                                                                                                SEWICKLEYSEAM
                                                                                                FIGURE  A-4

-------
I 1
en
                                                                                   WESTVIRGINIA

                                                                                   SEWICKLEY SEAM


                                                                                   FIGURE A-5

-------
OHIO
SEWICKLEYSEAM

FIGURE A-6

    107

-------
ORIGINAL
PROGRAM
SAMPLE
                                                           PENNSYLVANIA
                                                           PITTSBURGH SEAM
                                                          FIGURE A-7

-------
WEST VIRGINIA
PITTSBURGH SEAM

FIGURE A-8

-------
OHIO
PIHSBURGH SEAM
FIGURE A-9

    110

-------
PENNSYLVANIA
UPPER FREEPORT (NO 7))SEAM
FIGURE  A-10

-------
!  •
                                                                                   WEST VIRGINIA
                                                                                   UPPER FREE PORT  (NO 7) SEAM

                                                                                   FIGURE A-ll

-------
        HOLMES


                                      / JEFFERSON
OHIO
UPPER FREEPORT (NO 7) SEMI
FIGURE  A-12


    113

-------
                                                         MC KEAN
                                                                               POTTER
                                                                     c.M-11 I'lill
                                                                                                     TIOGA
                                                                                                                             BRADFORD
                                                                                                                                                   SUSQUEHANNA
                                                                                                                                             WYOMING

                                                                                                                              SULLIVAN    /             /LACKAWANNA
                                                                                                           LYCOMING
                                                                                     CLINTON
                                                                                                                                                                       WAYNE
                                                                                                                                                                               PIKE
                                                                                                                                               LUZERNE
                                                           11 i M'\ inn
                                                                                   i I till'
                                                                                                             UNION
                                                                                                           SNYDER
                                        INDIANA
                                                                                                                       O
                                                                                                                           0  _
                                                                                                                           4

                                                                                                                          *
                                                                                                                                 COLUMBIA
                                                                                                                                                        CARBON
                                                                                                                                                                      MONROE
                                                                                                                                                                 NORTHAMPTON .
                                                                                                                                      SCHUYLKILL
                                                                                                                                                             LEHI6H
                                                                                         MIFFLIN
                                                                                                  JUNIATA

                                                    CAMBRIA   /    BLAH
                               RELAND
                                                                          HUNTINGDON
WASH I';



                                                             BEDFORD
                                                                               m    FRANKLIN
                                                                                                       PERRY
                                                                                                   CUMBERLAND
                                                                                                        ADAMS
                                                                                                                     DAUPHIN
                                                                                                                                                   BERKS
                                                                                                                                 LEBANON
                                                                                                                                                                              BUCKS
                                                                                                                                       LANCASTER
                                                                                                                                                                    MONTGOMERY
CHESTER     y      "I •*•'
            DELAWARE
                                                                                                                         YORK
                                                                                     PENNSYLVANIA
                                                                                     LOWER  FREEPORT (NO 6A)  SEAM
                                                                                     FIGURE  A-13

-------
' I
                                                                                   WEST VIRGINIA
                                                                                   LOWER  FREEPORT (NO 6A) SEAM

                                                                                   FIGURE A-14

-------
•\J
                              OHIO
                              LOWER FREEPORT (NO 6A) SEAM
                              FIGURE A-15

                                  116

-------
PENNSYLVANIA
UPPER KITTANNING SEAM

FIGURE A-16

-------

WEST VIRGINIA
UPPER KITTANNING SEAM
FIGURE A-17

-------
        HOLMES
OHIO
UPPER KITTANNING SEAM

FIGURE A-18
    119

-------
PENNSYLVANIA
MIDDLE KITTANNING (NO 6) SEAM

FIGURE  A-19

-------
WEST VIRGINIA
MIDDLE KITTANNING (NO 6) SEAM

FIGURE  A-20

-------
OHIO
MIDDLE KITTANNING (N061SEAM

FIGURE  A-21

    122

-------

PENNSYLVANIA
LOWER KITTANNING SEAM
FIGURE A-22

-------
I '
! •
                                                                                  WEST VIRGINIA
                                                                                  LOWER KITTANNINGSEAM

                                                                                  FIGURE A-23

-------
OHIO
LOWER KIHANNING SEAM
FIGURE A-24

    125

-------
OHIO
CLARION 4A SEAM

FIGURE A-25

    126

-------
i '
 1
                                                                 EASTERN KENTUCKY

                                                                 MASON SEAM


                                                                 FIGURE A-26

-------
ILLINOIS
       5RISBURG - SI
             128

-------
INDIANA
SPRINGFIELD - NO.I SEAM

FIGURE A-28

    129

-------
WESTERN KENTUCKY
NO. 9 SEAM
FIGURE A-29

-------
ILLINOIS
        131

-------
, o
I  I
                                                                    WESTERN KENTUCKY

                                                                    NO. 11 SEAM

                                                                    FIGURE A-31

-------
INDIANA
HYMERA - NO.ST SEAM
FIGURE NO. A-32

        133

-------
                 APPENDIX B
   RANKING OF TREATED AND UNTREATED COALS
NOTE:  The values used for the calculations
       in this appendix are the average of
       the triplicate determinations  detailed
       in Appendices C and D.

       The EPA standard % sulfur will  yield
       1.2 Ibs S02/106 btu.
                      134

-------
                                                                 Table  B-l
                                                 COAL  RANKING  DATA-UNTREATED COAL
                                                           FINAL  TWENTY COALS
Mine
Muskinaum
Powhattan No. 4
Isabella
Mathies
Williams
Robinson Run
Shoemaker
Delmont
Marion
Lucas
Bird No. 3
Martinka
Meigs
Dean
Kopperston
Harris Nos. 1&2
North River
Homestead
Ken
Star
Seam
Meigs Creek
No. 9
Pittsburgh No. 8
Pittsburgh
Pittsburgh
Pittsburgh
Pittsburgh
Pittsburgh
Upper Freeport
Upper Freeport
Middle
Kittanning
Lower
Kittanning
Lower
Kittanning
Clarion 4A
Dean
Campbell Creek
Eagle & No. 2
Gas
Corona
No. 11
No. 9
No. 9
Moisture
%
3.36
2.10
1.57
2.15
1.28
0.96
1.51
0.77
1.84
3.88
0.84
1 .84
4.77
1.06
1.38
1.72
1.57
5.41
4.76
6.13
Sulfur
%
6.08
4.12
1.57
1.46
3.48
4.38
3.51
4.89
1.37
1.79
3.14
1.96
3.73
4.09
0.91
1.00
2.06
4.46
4.83
4.32
Ash
%
21.68
37.17
42.22
41.01
13.18
13.36
33.48
27.18
26.40
8.68
30.23
49.64
26.53
17.28
30.15
18.63
49.25
16.56
15.08
13.90
BTU
Moist
10644
8422
8087
7979
12846
12838
9352
10927
10843
12929
10461
7413
9757
11979
10806
12200
7572
11289
11523
11554
Dry
11014
8603
8216
8154
13013
12962
9495
11012
11046
13451
10550
7552
10246
12107
10957
12414
7693
11935
12099
12308
Moist
Mineral
Matter
Free
14118
14267
14958
14399
15113
15173
14821
15720
15232
14323
15702
16144
13811
14887
16075
15316
16352
13892
13918
13724
Dry
Mineral
Matter
Free
14608
14573
15197
14715
15309
15321
15049
15842
15517
14902
1 5835
16447
14503
15047
16300
15585
16613
14686
14614
14620
Fixed
Dry
41.96
33.82
33.09
34.46
48.18
47.76
35.39
44.49
49.15
56.02
53.59
28.76
38.55
45.81
45.96
54.51
27.56
50.30
49.66
52.16
Carbon
Dry
Mineral
Matter
Free
56.04
57.65
61.37
62.36
56.84
56.64
56.31
64.39
69.19
62.19
80.94
62.82
54.82
57.15
68.46
68.52
59.66
62.30
60.37
62.35
Volatile Matter
Dry
36.36
29.01
24.69
24.53
38.64
38.88
31.13
28.33
24.45
35.30
16.18
21.60
34.92
36.91
23.89
26.86
23.19
33.14
35.26
33.94
Dry
Mineral
Matter
Free
43.96
42.35
38.63
37. 6*
43.16
43-. 36
43.69
35.61
30.81
37.81
19.06
37.18
45.18
42.85
31.54
31.48
40.34
37.70
39.63
37.65
EPA
Standard
% Sulfur
0.66
0.52
0.49
0.49
0.78
0.78
0.57
0.66
0.66
0.81
0.63
0.45
0.61
0.73
0.66
0.74
0.46
0.72
0.73
0.74
Class
II-3
II-3
II-3
II-3
II-3
II-3
II-3
II-3
II-2
II-3
II-l
II-3
II-4
II-3
II-3
II-3
II-3
II-4
II-4
II-4
GO
en
      Class:  H-1, Bituminous - Low Volatile (Ivb)
            II-2, Bituminous - Medium Volatile (mvb)
            II-3, Bituminous - High Volatile A (hvAb)
            II-4, Bituminous - High Volatile B (hvBb)

-------
                                                       Table B-2

                                         COAL  RANKING DATA - UNTREATED COAL
                                                 INITIAL FIFTEEN COALS
Mine
Edna
Navajo
Belle Ayr
Colstrip
Me 1 don
Eagle No. 2
Orient No. 6
Camp Nos. 1 & 2
Walker
Egypt Valley
No. 21
No. 1
Jane Nos. 1 & 2
Fox
Warwick
Humphrey No. 7
Seam
Wadge
Nos. 6, 7, 8
Roland-Smith
Rosebud
Des Moines No. 1
Illinois No. 5
Herri n No. 6
Seam No. 9
Upper
Kittanning
Pittsburgh No. 8
Mason
Lower Freeport
Lower
Kittanning
Sewickley
Pittsburgh No. 8
Moisture
8.41
11.07
19.14
20.41
13.29
3.31
3.51
3.99
2.07
2.07
2.22
1.17
1.83
1.50
1.63
Sulfur
0.75
0.81
0.76
1.01
6.39
4.29
1.66
4.51
0.71
6.55
3.12
1.85
3.83
1.37
2.58
Ash
*
9.13
25.29
7.55
10.38
15.74
26.53
22.51
21.13
16.67
25.29
11.39
21.75
13.55
40.47
9.88
Bl 1
Moist
11216
8937
9731
9225
10197
10216
10771
10662
12341
10375
12764
11792
12736
8483
13409
Dry
12246
10050
12034
11591
11760
10566
11163
11105
12602
10594
13054
11932
12973
8612
13631
Mineral
Matter
Free
12458
12316
10601
10398
12427
14498
14294
13971
15079
14543
14664
15498
15066
15150
15106

Dry "
Mineral
Matter
Free
13602
13849
13111
13065
14331
14994
14814
14552
15398
14851
14997
15682
15347
15381
15356

Dry
50.22
39.20
45.34
46.53
43.64
39.17
45.82
43.01
64.44
38.59
49.70
48.18
48.12
31.76
52.46
Dry
Minera
Matter
Free
55.84
54.09
49.47
52.56
53.70
55.85
60.94
56.67
78.83
54.44
57.26
63.45
57.11
56.82
59.23
Class: II-l, Bituminous - Low Volatile III-l, Subbi luminous A
II-2, Bituminous - Medium Volatile III-2, Subbltuminous B
II-3, Bituminous - High Volatile A
II-4, Bituminous - High Volatile B
II-5, Bituminous - High Volatile C

Dry
40.65
35.51
47.11
43.09
40.62
34.30
31.67
35.86
18.89
36.12
38.91
30.07
38.33
27.77
37.66

Dry 	 "
Mineral
Matter
Free
44.16
45.91
50.53
47.44
46.30
44.15
39.06
43.33
21.17
45.56
42.74
36.55
42.89
43.18
40.77

EPA
Standard
% Sulfur
0.73
0.60
0.72
0.70
0.71
0.63
0.67
0.67
0.76
0.64
0.78
0.72
0.78
0.52
0.82

Class
II-5
II-5
II-5/
III-2
II-5
II-3
II-3
II-4
II-l
II-3
II-3
II-3
II-3
II-3
II-3

CO
cr>

-------
                                                               Table  B-3

                                          COAL  RANKING DATA -  PYRITIC SULFUR  EXTRACTIONS
                                                            FINAL TWENTY COALS
Mine
Muskingum
Powhattan No. 4
Isabella
Mathies
Williams
Robinson Run
Shoemaker
Delmont
Marion
Lucas
Bird No. 3
Martinka
Meigs
Dean
Kopperston
Harris Nos. 1&2
North River
Homestead
Ken
Star
Seam
Meiqs Creek
No. '9
Pittsburgh No. 8
Pittsburgh
Pittsburgh
Pittsburgh
Pittsburgh
Pittsburgh
Upper Freeport
Upper Freeport
Middle
Kittanning
Lower
Kittanning
Lower
Ki ttanninq
Clarion 4A
Dean
Campbell Creek
Eagle & No. 2
Gas
Corona
No. 11
No. 9
No. 9
Moisture
%
3.36
2.10
1.57
2.15
1.28
0.96
1.51
0.77
1.84
3.88
0.84
1 .84
4.77
1.06
1.38
1.72
1.57
5.41
4.76
6.13
Sulfur
%
3.22
2.04
0.72
0.94
1.74
2.20
1.87
0.96
0.68
0.89
0.80
0.58
1.94
2.08
0.61
0.77
0.93
2.38
2.78
2.46
Ash
%
16.05
32.12
35.72
36.43
9.16
7.63
28.87
20.44
22.61
6.32
24.17
43.46
20.38
13.66
25.53
16.46
42.84
11.50
9.44
8.58
BTU
Moist
11189
9281
9166
8830
13413
13632
10003
12015
11504
13345
11403
7988
10535
12529
11184
12340
8192
11602
12085
11875
Dry
11578
9480
9312
9024
13587
13764
10156
12108
11720
13884
11500
8138
11063
12663
11340
12556
8323
12266
12689
12650
Moist
Mineral
Matter
Free
13632
14300
14960
14605
14948
14933
14617
15462
15252
14351
15470
15090
13570
14773
15470
15039
15306
13311
13533
13148
Dry
Mineral
Matter
Free
14106
14607
15199
14925
15142
15078
14841
15582
15538
14930
15601
15373
14250
14932
15687
15302
15550
14072
14209
14006
Fixed Carbon
Dry
47.00
38.60
40.27
38.06
52.06
57.16
41.33
49.75
52.08
58.53
58.26
34.41
44.35
52.08
46.78
52.76
33.42
52.58
54.26
56.43
Dry
Minera'
Matter
Free
57.50
59.66
65.81
63.05
58.10
62.76
60.55
64.09
69.11
63.01
79.15
65.07
57.28
61.55
64.76
64.36
62.53
60.53
60.99
62.72
Volatile Matter
Dry
36.95
29.28
24.01
25.51
38.78
35.21
29.80
29.81
25.31
35.15
17.57
22.13
35.27
34.26
27.69
30.78
23.74
35.92
36.30
34.99
Dry
Minera
Matter
Free
42.50
40.34
34.19
36^95
41.90
37.24
39.45
35.91
30.89
36.99
20.85
34.93
42.72
38.45
35.24
35.64
37.47
39.47
39.01
37.28
EPA
Standard
% Sulfur
0.69
0.57
0.56
0.54
0.82
0.83
0.61
0.73
0.70
0.83
0.69
0.49
0.66
0.76
0.68
0.75
0.50
0.74
0.76
0.76
Class
II-4
II-3
II-3
II-3
II-3
II-3
II-3
II-3
11-2
II-3
II-l
II-3
II-4
II-3
II-3
II-3
II-3
II-4
II-4
II-4
CO
      Class:
         II-l,  Bituminous
         II-2,  Bituminous
         11-3,  Bituminous
         II-4,  Bituminous
Low Volatile
Medium Volatile
High Volatile A
Hiqh Volatile B

-------
                                                          Table  B-4

                                      COAL RANKING DATA - PYRITIC SULFUR EXTRACTIONS

                                                    INITIAL FIFTEEN COALS
Mine
Edna
Navajo
Belle Ayr
Colstrip
Wei don
Eagle No. 2
Orient No. 6
Camp Nos. 1 and 2
Egypt Valley
No. 21
No. 1
Jane Nos. 1 and 2
Fox
Warwick
Humphrey No. 7
Seam
Wadge
Nos. 6,7,8
Roland-
Smith
Rosebud
Des Moines
No. 1
111 inois
No. 5
Herrin
No. 6
Seam No. 9
Pittsburgh
No. 8
Mason
Lower
Free port
Lower Kit-
tanning
Sewickley
Pittsburgh
No. 8
Moisture
%
8.41
11.07
19.14
20.41
13.29
3.31
3.51
3.99
2.07
2.22
1.17
1.83
1.50
1.63
Sulfur
%
1.14
0.76
0.82
0.69
2,34
2.12
1.40
2.77
2.09
1,62
0.67
1.64
0.82
1.49
Ash
6.77
20.53
3.37
5.17
5.43
19.80
18.85
15.77
18.86
8.50
17.99
9.72
35.32
6.97

Moist
11175
8924
9315
9010
10833
11024
10G47
11272
11268
13045
12272
12933
9225
13722

Dry
12201
10035
11520
11321
12493
11401
11034
11740
11506
13341
12417
13174
9365
13949
BTU
Moist
Mineral
Matter
Free
12077
11479
9670
9545
11677
14096
13410
13669
14253
14416
15259
14504
14956
14890

Dry
Mineral
Matter
Free
13186
12908
11958
11993
13467
14579
13898
14238
14554
14743
15440
14775
15184
15137
Fixed Carbon
Dry
50.88
43.65
49.61
52.38
54.96
45.70
49.23
47.78
43.06
53.87
51.65
51.97
38.07
55.99
Dry
Mineral
Matter
Free
55.08
56.24
51.60
55.59
59.51
58.60
62.15
58.16
54.62
59.63
64.27
58.38
61.80
60.85
Volatile Matter
Dry
42.35
35.82
47.02
42.45
38.61
34.50
31.92
36.45
38.08
37.63
30.36
33.31
26.61
37.04
Dry
Mineral
Matter
Free
44.92
43.76
48.40
44.41
40.49
41.40
37.85
41.84
45.38
40.37
35.73
41.62
38.20
39.15
EPA
Standard
y. Sulfur
0.73
0.60
0.69
0.68
0.75
0.68
0.66
0.70
0.69
0.80
0.75
0.79
0.56
0.84
Class
II-5
II-5/
III-l
III-2
III-2
II-5
II-3
II-4
II-4
II-3
II-3
II-3
II-3
II-3
II-3
Class:
II-l , Bituminous-Low Volatile (Ivb)
II-2, Bituminous-Medium Volatile (mvb)
II-3, Bituminous-High Volatile A (hvAb)
II-4, Bituminous-High Volatile B (hvBb)
I II-l , Subbituminous A
CO
oo
        III-2, Subbituminous B

-------
                                Table B-5

                       COMPUTER PROGRAM FOR DETERMINING

                              THE RANK OF COAL
      PROGRAM RANK  
-------
  7 FORMAT (*EFA STANDARD-%  SULFUF.=** F4. 2* *%* )
 55 PRINT  5
  5 FORMAT <*RANK=*>
    RANK SORTING
    IF  (DRYFC-98.) 11*10*10
 11 IF  (BRYFC-92.) 12*20*20
 12 IF  CDBYFC-86. ) 13*30,30
 13 IF  (DRYKO78.) 14*40*40
 14 IF  (DBYFC-69.) 15*50*50
 15 IF  (WETBTU-I4000-)  16*60*60
 16 IF  (WETBTU-13000.>  17*70*70
 17 IF  (WETBTU-11500.)  18*80*80
 18 IF  (WETBTU-10500. >  19*90*90
 19 IF  
-------
 110
 120
 130

1111
  21
  31
  41
  51
  61
  71
  81
  91

 101
 111
 121
 131
1000
 700

  68
 PRINT
 WRITE
 GO TO
 PRINT
 WRITE
  GO TO
       111
       ( 6, 1 11 )
       1000
       121
       (6, 121)
        1000
 PRINT  131
 WRITE  <6* 131)
 FORMAT
 FORMAT
 FORMAT
 FORMAT
 FORMAT
 FORMAT
 FORMAT
 FORMAT
 FORMAT
        C*CLASS
        (*CLASS
        <*CLASS
        (*CLASS
        C*CLASS
        (*CLASS
        (*CLASS
        C+CLASS
        (*CLASS
1-1* META-ANTHRACITE*)
1-2* ANTHRACITE*)
1-3* SEMI ANTHRACITE*)
II-l* BITUMINOUS-LOW VOLATILE*)
11-2* BITUMINOUS-MEDIUM  VOLATILE*)
11-3* BITUMINOUS-HIGH VOLATILE A*)
11-4, BITUMINOUS-HIGH VOLATILE B*)
11-5* BITUMINOUS-HIGH VOLATILE C* )
II-5* BITUMINOUS-HIGH VOLATILE C* *
1*AGGLOMERATING*/*CLASS  111-1*SUBBITUMINOUS A*NONAGGLOMERATING*)
 FORMAT  (*CLASS III-2* SUBBITUMINOUS B*)
                 111-3* SUBBITUMINOUS C*)
                 IV-1* LIGNITE A*)
                 IV-2* LIGNITE B*)
  69
FORMAT (*CLASS
FORMAT <*CLASS
FORMAT <* CLASS
PRINT  700
FORMAT 
-------
         APPENDIX C
UNTREATED COAL ANALYSES DATA
             142

-------
                                                      Table  C-l
                                               UNTREATED COAL ANALYSES
                             MUSKINGUM,  POWHATTAN NO. 4,  ISABELLA AND MATHIES MINES

Mine, Seam, and
Location


Muskingum Mine
Meigs Creek No. 9
Morgan County
Ohio

Powhattan No. 4
Pittsburgh No. 8
Monroe County
East Ohio

Isabel la Mine
Pittsburgh Seam
Fayette County
Pennsy Ivan ia

Mathies Mine
Pittsburgh Seam
Washington County
Pennsy Ivan i a


C antnl a
Oaulp 1 6


A
B
C
Average
Std. Dev,
A
B
C
Average
Std. Dev.
A
B
C
Average
Std. Dev.
A
B
C
Average
Std. Dev
As Received
Basis

Moisture
% w/w
3.32
3.40
3.35
3.36
±.040
2.16
1.85
2.29
2.10
±.225
1.66
1.56
1.50
1.57
+ .081
2.31
2.18
2.15
2.15
+ .025

Dry Forms of Sulfur, % w/w


Total
5.96
6.10
6.18
6.08
±0.111
4.08
4.08
4.21
4.12
±.075
1.54
1.58
1.58
1.57
+ .023
1.45
1.44
1.48
1.46
±.021


Pyritic
3.64
3.66
3.65
3.65
±0.010
2.51
2.57
2.63
2.57
+.060
1.14
1.06
1.00
1.07
±.070
0.98
1.05
1.11
1.05
±.065


Sulfate
0.08
0.05
0.04
0.06
±.021
0.18
0.21
0.19
0. 19
±.015
0.04
0.04
0.04
0.04
+ .00
0.04
0.04
0.04
0.04
±.00


Organic
2.24
2.39
2.4?
2.37
t.113
1.39
1.30
1.39
1.36
±.097
0.36
0.48
0.54
0.46
+ .074
0.43
0.35
0.33
0.37
±.068

Dry Proximate Analysis, % w/w


Ash
21.58
21.75
21 .72
21.68
±.091
37.07
37.67
36.77
37.17
±.458
42.37
42.18
42.12
42.22
+ .131
41.03
4i.03
40.96
41.01
±.040


Volatiles
•' 37.49
35.97
35.63
36.36
±.990
28.66
29.03
29.35
29.01
±.345
24.71
24.62
24.74
24.69
+ .062
24.41
24.43
24.75
24.53
±.191

Fixed
Carbon
' 40.93
42.28
42.65
41.96
±.994
34.27
33.30
33.88
33.82
±.573
32.92
33.20
33.14
33.09
+ .145
34.56
34.54
34.29
34.46
+ .150
Heat
Content
btu
11030
10981
11033
11014
±29.2
8522
8520
8769
8603
±143.2
8223
8197
8227
8216
±16.2
8289
8028
8146
8154
±130.6
oo

-------
                     Table C-2
               UNTREATED COAL ANALYSES
WILLIAMS, ROBINSON RUN, SHOEMAKER AND DELMONT MINES

Mine, Seam, and
Location
Wi 1 1 iams Mine
Pittsburgh Seam
Marion County
West V i rgin ia

Robi nson Run Mine
Pittsburgh Seam
Harrison County
West V i rgini a

Shoemaker Mine
Pittsburgh Seam
Marshal 1 County
West Vi rginia

Delmont Mine
Upper Freeport
Westmoreland County
Pennsy 1 vania


Sample

A
8
c
Average
Std. Dev.
A
B
C
Average
Std. Dev.
A
B
C
Average
Std. Dev.
A
B
C
Average
Std. Dev.
As Received
Basis
Moisture
% w/w
1.33
1.25
1.25
1.28
±.046
0.93
0.94
1 .00
0.96
±.038
1.49
1.54
1.50
1.51
±.025
0.81
0.77
0.7*4
0.77
±.035

Dry Forms of Sulfur, % w/w
Total
3.49
3.48
3.47
3.48
±.010
4.36
4.42
4.37
4.38
±.032
3.51
3.52
3.50
3.51
±.010
it. 86
4.91
4.90
4.89
±.025
Pyritic
2.18
2.21
2.30
2.23
±.062
2.88
2.70
3.08
2.89
±.190
2.09
2.29
2.20
2.19
±.100
4.61
4.53
4.54
4.56
±.044
Sulfate
0.04
0.05
0.04
0.04
±.006
0.06
0.06
0.06
0.06
±.00
0.05
0.05
0.05
0.05
±.00
0.08
0.08
0.08
0.08
±.00
Organic
1.27
1.22
1.13
1.21
'.063
1.42
1.66
1.23
1.43
±.193
1.37
1.18
1.25
1.27
±. 100
0.17
0.30
0.28
0.25
±.051

Dry Proximate Analysis, % w/w
Ash
13.19
13.11
13.25
13.18
±.070
13.43
13.20
13.45
13.36
±.139
33.61
33.48
33.36
33.48
±.125
27.40
26.92
27.22
27.18
±.242
Volatiles
38.50
38.47
38.94
38.64
+ .263
39.01
39.15
38.49
38.88
±.348
30.94
31.10
31.35
31.13
+ .207
28.45
28.08
28.47
28.33
+ .220
Fixed
Carbon
48.31
48.42
47.81
48.18
±.272
47.56
47.65
48.06
47.76
±.375
35.45
35.42
35.29
35.39
±.242
44.15
45.00
44.31
44.49
±.327
Heat
Content
btu
12947
13069
13025
13013
±61.6
12912
13022
12951
12962
+ 56.8
9512
9486
9488
9495
±14.5
11044
10981
1101 1
11012
±31.5

-------
                                                      Table C-3
                                                UNTREATED COAL ANALYSES
                                     MARION, LUCAS, BIRD NO. 3, AND MARTINKA MINES
Mine, Seam, and
Location
Marion Mine
Upper Freeport Seam
Indiana County
Pennsylvania

Lucas Mine
Middle Ki ttanning
Columbiana County
Ohio

Bi rd No. 3 Mine
Lower Ki ttanni ng
Sommerset County
Pennsy 1 van ia

Martinka Mine
Lower Kittanning
Logan or Mingo
West Vi rginia

Sample
A
D
c
Average
Std. Dev.
A
B
C
Average
Std. Dev.
A
B
C
Average
Std. Dev.
A
B
C
Average
Std. Dev.
As Received
Basis
Moisture
% w/w
1.71
1.69
2.13
1.84
±.248
3.89
3.88
3.86
3.88
±.015
0.88
0.82
0.83
0.84
±.032
1.50
2.30
1.70
1.84
±.428
Dry Forms of Sulfur, % w/w
Total
1.37
1.34
1.39
1.37
±.025
1.93
1.73
1.71
1.79
±. 122
3.09
3.19
3.15
3.14
±.050
1.93
1.96
1 .98
1.96
±.025
Pyritic
0.92
0.89
0.8g
0.90
±.017
1.51
1.35
1 .40
1.42
±.082
2.82
2.94
2.85
2.87
±.062
1.59
1.62
1.63
1.61
±.021
Sulfate
0.00
0.03
0.03
0.02
±.017
0.05
0.05
0.05
0.05
±.00
0.05
0.05
0.05
0.05
±.00
0.10
0.09
0.09
0.09
±.006
Organic
0.45
0.42
0.47
0.45
±.035
0.37
0.33
0.26
0.32
±.147
0.22
0.20
0.25
0.22
±.080
0.24
0.25
0.26
0.26
±.033
Dry Proximate Analysis, % w/w
Ash
26.46
26.44
26.31
26.40
+ .081
fi.66
8.78
8.61
8.68
±.087
30.12
30.58
29.99
30.23
±.310
49.60
49.65
49.68
49.64
+ .040
Volatiles
"24.70
24.59
24.06
24.45
±.342
35.48
35.30
35.12
35.30
±. 180
16.19
16.09
16.25
16.18
+ .081
21.94
21.66
21.54
21.60
±.085
Fixed
Carbon
48.84
48.97
49.63
49.15
±.423
55.86
55.92
56.27
56.02
+ .221
53.69
53.33
53.76
53.59
+ .320
28.46
28.69
28,78
28.76
+ .094
Heat
Content
btu
1 1076
11039
1 1024
1 1046
+ 26.8
13520
13443
13390
13451
+65.4
10554
10495
10600
10550
±52.6
7548
7550
7559
7552
+5.9
en

-------
                       Table C-4
                UNTREATED COAL ANALYSES
MEIGS, DEAN, KOPPERSTON NO. 2, AND HARRIS NOS.  1  & 2 MINES
Mine, Seam, and
Location
Mei gs M i ne
Clarion 4A Seam
Meigs County
Ohio

Dean Mine
Dean Seam
Scott County
Tennessee

Kopperston Mine
Campbell Creek Sea
Wyoming County
West Virginia

Harris Nos. 1 & 2
Mines
Eagle and No. 2 Gas
Seams
Boone County ,
West Virginia
Sample
A
B
C
Average
Std. Dev.
A
B
C
Average
Std. Dev.
A
B
C
Average
. Std. Dev.
A
B
C
Average
As Received
Basis
Moisture
% w/w
it. 77
4.79
4.74
4. 77
±.025
1.13
1.08
.96
1.06
..087
1.40
1.40
1.34
1.38 •
-.035
1.74
1.72
1.71
1.72
±.015
Dry Forms of Sulfur, % w/w
Total
3.69
3.73
3.76
3.73
±.035
4.11
4.10
4.06
4.09
±.026
0.95
0.86
0.93
0.91
'.047
1.01
1.00
1.00
1.00
±.006
Pyritic
2.22
2. 19
2.16
2.19
±.030
2.64
2.69
2.52
2.62
' .087
0.49
0.44
0.48
0.47
±.026
0.52
0.45
0.50
0.49
±.036
Sulfate
0.06
0.06
0.05
0.06
±.006
0.15
0.15
0.15
0.15
±0.00
0.04
0.04
0.02
0.03
'.012
0.03
0.03
0.03
0.03
±.00
Organic
i .41
1.48
1.55
1.48
±.046
1.32
1.26
1.39
1.32
'.091
0.42
0.38
0.43
0.41
-.055
0.46
0.52
0.47
0.48
±.036
Dry Proximate Analysis, % w/w
Ash
26.49
26.39
26.71
26.53
±.164
17.42
1 6 . 9.7
17.46
17.28
•0.272
30.10
30.15
30.20
30.15
'0.050
18.62
18.69
18.58
18.63
±0.056
Volatiles
35.46
34.61
34.70
34.92
±.467
39.09
3e.5?
35.13
36.91
-2.01
23.99
23.69
23.99
23.89
^0.173
26.76
26.71
27.12
26.86
±0.224
Fixed
Carbon
38.05
39.00
38.59
38.55
±.495
45.49
46.51
47.41
45.81
-2.03
45.91
46.16
45.81
45.96
±0.180
54.62
54.60
54.30
54.51
±0.231
Heat
Content
htu/lb
10240
10255
10243
10246
±7.9
12153
12088
12080
12107
•40.0
10941
10986
10945
10957
•24.9
1237
12434
12439
12414
±38.5

-------
                 Table C-5
          UNTREATED COAL ANALYSES
NORTH RIVER, HOMESTEAD, KEN AND STAR MINES

Mine, Seam, and
Location


:iortn River Mine
Corona Seam
Jefferson County
Alabama

Homestead Mine
:io. 11 Seam
On'o County
west Kentucky

Ken Mine
No. 9 Seam
Ohic County
West Kentucky

Star Mine
No. 9 Seam
'.iopkins County
Vest Kentucky

Sample



n
C
Average
Std. Dev.
A
L
r
^-
Average
Std. Dev.
A
•i
r
"verage
Std. ::ev.
r.
F
C
Average
Std. Jev.
As Received
Basis

Moisture
% w/w
1.51
1 .57
1.54
l.:7
i . 035
5.47
5.39
5.38
5.41
:.C49
4.77
4.79
4.71
4.76
+ .042
6.16
6.14
6.00
6.13
±.038

Dry Forms of Sulfur, % w/w


Total
2.r:7
2.06
2.C4
2 . Of.
t .Olb
4.47
4.45
4.46
4.46
+ .010
4.^6
4.79
.'..84
4.83
-.336
4.30
4.32
4.35
4.32
±.025


Pyritic
1.42
1.44
1.40
1.42
± .020
3.12
3.17
3.05
3.11
t.049
2.83
2.83
2.89
2.85
* .038
2.50
2.60
2.70
2.60
±.100


Sulfate
0/7
' . 07
O.T7
0.07
i . "'O
0.10
O.io
0.11
0.11
* ,00f
. 0.26
0.25
0.2*
0.26
•.oor
0.27
0.22
0.22
0.24
±.029


Organic
o.58
0.55
O.F7
0.57
+ .°25
1.2^
1,21
1.30
1.25
T.n31
1.72
1.72
1.69
1.72
±.053
1.58
' 1.50
1.43
1.50
±.075

Dry Proximate Analysis, % w/w


Ash
19.21
4^ . ?5
A° . 30
4^.25
:' .04E
16.54
16.56
16.57
16.56
+ .150
15.06
15.03
15.14
15. OR
±.057
13.89
1 3 . 84
13.98
13.90
±.071


Volatiles
23.26
23. IS
23. T;
23.1"
+ .058
32.77
33.80
32.85
33.14
+ .573
34.30
35 . 63
35.85
35.26
+ .839
35.14
33.56
33.12
33.94
±1.062

Fixed
Carbon
27.53
' 27.5°
27.5° .
27.56
±.073
50.69
49.64
50.58
50.30
+ .592
50.64
49.34
49.01
49.66
±.841
56.97
52,60
52,90
52.16
±1.064
Heat
Content
btu/lb
771 r
7692
1-1J,
7?93
±21.
11966
11962
11878
11935
±49.7
12127
12063
12107
12099
±32.7
12275
12309
12340
12308
±35.5

-------
                   APPENDIX  D
           PYRITIC SULFUR REMOVAL  DATA
NOTE:  The complete general procedure used
       to treat the coals is contained in
       Section 4.3 of this report.   Variables
       such as mesh, reaction time, and leach
       numbers and times are listed in the
       tables.  Numbers in parentheses are
       not considered valid for various
       reasons but are included for
       completeness.  Averages are  included
       only where appropriate.
                       148

-------
                     Table D-l
             PYRITIC SULFUR REMOVAL DATA
MUSKINGUM, POWHATTAN NO. 4, ISABELLA AND MATHIES MINES

line, Seam,
and Location
Muskingum Mine
Melgs Creek No. 9
Morgan County

Ohio

Powhattan No. 4
Pittsburgh No. 8
Monroe County

East Ohio



Isabella Mine
Pittsburgh Seam
Fayette County

Pennsylvania

Mathies Mine
Pittsburgh Seam
Washington County
Pennsylvania

Mesh

150
150




100
100





200
100
100




150
150


Total
Rxn.
Time
23
23




23
23





23
23
23




23
23


Leach Changes

Number Time (hrs)
1 5.0
1 5.0
Treated Average
Std. Dev.
Initial Average
Std. Dev.
1 9.0
1 9.0
Treated Average
Std. Dev.
Initial Average
Std. Dev.

1 4.5
0
0
Treated Average
Std. Dev.
Initial Average
Std. Dev.
0
0
Treated Average
Std. Dev.
Initial Average
Std. Dev.

Run
Number
1
2
1-2

A-C

1
2
1-2

A-C


3
1
2
1-2

A-C

1
2
1-2
A-C

Total
Sulfur
3.24
3.20
3.22
+ .028
6.08
± . 1 1 1
2.04
2.03
2.04
1.007
4.12
±.075
1 .94

0.71
0.72
0.72
±.007
1.57
±.023
0.95
0.92
0.94
±.021
1.46
±.021
)ry Forms of Sulfur. % w/w

Pyritic
0.24
0.27
0.20
0.26
0.24
±.031
3.65
±.010
n.41
0.39
0.50
0.47
0.44
±.051
2.57
±.060
0.04

0.05
0.07
0.06
0.07
0.06
±.010
1.07
±.070
0.08
0.02
0.08
0,02
0.05
±.035
1.05
±.065

Sulfate
0.18
0.16
0.17
±.014
0.06
±.021
0.11
0.13
0.12
±.014
0.19
±.015
0.10

0.00
0.01
0.01
±.007
0.04
±0.00
0.10
0.10
0.10
±.00
0.04
±.00

Organic
2.80
2.81
2.81
±044
2.37
±.113
1.53
1.42
1.48
±.053
1.36
±.097
1.80

0.51
0.41
0.65
±.014
0.46
±.074
0.80
0.87
0.79
±.041
0.37
±.068
Dry Proximate Analysis, % w/w

Ash
16.11
15.99
16.05
•±.085
21.68
±.990
31.76
32.48
32.13
±.509
37.17
±.458


35.61
35.83
35.72
±.156
42.22
±.131
36.16
36.70
36.43
±.382
41.01
±.040
Volatile
Matter
36.96
36.94
36.95
+ .014
36.36
±.990
29.26
29.29
29.28
±.021
29.01
±.345


24.35
23.67
24.01
±.481
24.69
±.062
26.11
24.91
25.51
±.849
24.53
±.191
Fixed
Carbon
46.93
47.07
47.00
±.086
41.96
±.994
38.98
38.23
38.60
±.509
33.82
±.573


40.04
40.50
40.27
±.506
33.09
±.145
37.73
38.39
38.06
±.931
34.66
±.150

btu/lb
11546
11611
11578
±46.0
11014
±29.2
9529
9431
9480
±69.3
8603
±143.2


9321
9302
9312
±13.4
8216
±130.6
9071
8978
9024
±65.8
8154
±130.6

-------
01
o
                                                    Table  D-2

                                            PYRITIC SULFUR REMOVAL  DATA

                                  WILLIAMS, ROBINSON  RUN,  SHOEMAKER AND  DELMONT  MINES
Mine, Seam,
and Location
Williams Mine
Pittsburgh Seam
Marlon County

West Virginia


Robinson Run Mine
Pittsburgh Seam
Harrison County

West Virginia

Shoemaker Mine
Pittsburgh Seam
Marshall County

West Virginia


Delmont Mine
Upper Freeport
Westmoreland County

Pennsylvania

Mesh

100
100




150
150
150




100
100




150
200
200




Total
Rxn.
Time
23
23




23
23.5
23.5




23
23




23
23
23




Leach Changes

Number Time (hrs)
1 10
1 10
Treated Average
Std. Dev.
Initial Average
Std. Dev.

1 6
1 6
Treated Average
Std. Dev.
Initial Average
Std. Dev.
1 7
1 7
Treated Average
Std. Dev.
Initial Average
Std. Dev.
1 4.5
1 6
1 6
Treated Average
Std. Dev.
Initial Average
Std. Dev.
Run
Number
1
2
1-2

A-C

3
1
1
1-2

A-C

1
2
1-2

A-C

3
1
2
1-2

A-C

Dry Forms of Sulfur, % w/w

Sulfu
1.76
1.72
1.74
±.028
3.48
+ .010
1.80
2.20
2.19
2.20
+ .007
4.38
±.032
1.78
1.96
1.87
+ .127
3.51
+ .010
1.73
0.90
1.02
0.96
-.085
4.89
+ .025

Pyrltlc
0.25
0.32
0.32
0.27
0.29
+ .036
2.23
+ .062
0.10
0.09
0.09
0.07
0.07
0.08
±.012
2.89
±.190
0.34
0.38
0.55
0.55
0.46
+ .111
2.19
±.100
0.08
0.16
n. 11
0.27
0.30
0.21
+ .090
4.56
+ .044

Sulfate
0.06
0.06
0.06
+ .00
0.04
+.006 .
0.09
0.00
0.00
0.00
+ .00
0.06
+ .00
0.07
0.08
0.08
±.007
0.05
±.00
0.11
0.05
0.07
0.06
+ .014
0.08
+ .000

Organic
1.42
1.36
1.39
+ .046
1.21
+ .063
1.55
2.11
2.12
2.12
+ .014
1.43
'±.193
1.35
1.33
1.34
±.169
1.27
+ .100
1.7C
0.71
0.67
0.69
+ .125
0.25
1.051


Ash
9.19
9.12
9.16
+ .049
13.18
+ .070
8.58
7.47
7.79
7.63
±.226
13.36
+ .139
28.50
29.24
28.87
±.523
33.48
+ .125
27.24
20.14
20.74
20.44
+ . 424
27.18
±.242
Volatile
Matter
39.35
38.22
38.78
±.779
38.64
+ .263
36.26
35.31
35.11
35.21
+ .141
38.88
±.348
29.95
29.66
29.80
+ .205
31.13
+ .207
31.5C
29.95
29.67
29.81
+ .198
28.33
+ .220
FTxe3 	

51.46
52.66
52.06
±.801
48.18
+ .272
55.16
57.22
57.10
57.16
+ .266
47.76
+ .375
41.55
41.10
41.33
+ .562
35.39
+ .242
41.18
49.91
49.59
49.75
i.468
44.49
+ .327

btu/lb
13610
13564
13587
±32.5
13013
±61.6
13377
13793
13736
13764
+40.3
12962
±55.8
10131
10180
10156
±34.6
9495
+ 14.5
10195
12150
12067
12108
t58.7
11012
+ 31.5

-------
cn
                                                    Table D-3
                                            PYRITIC SULFUR REMOVAL DATA
                                    MARION, LUCAS, BIRD NO. 3, AND MARTINKA MINES
Mine, Seam,
and Location
Marion Mine
Upper Freeport Seam
Indiana County
Pennsylvania
Lucas Mine
Middle Kittanning
Columbia County
Ohio
Bird No. 3 Mine
Lower Kittanning
Sommerset County
Pennsylvania
Marti nka Mine
Lower Kittanning
Logan or Mingo
West Virginia
Mesh
100
TOO


100
100

150
150
150


IOC
100


Total
Rxn.
Time
23
23


23
23

23
23
23


23
23


Leach Changes
Number Time (hrs)
0
0
Treated Average
Std. Dev.
Initial Average
Std. Dev.
0
Treated Average
Std. Dev.
Initial Average
Std. Dev.
1 6
1 6
Treated Average
Std. Oev.
Initial Average
Std. Dev.
0
0
Treated Average
Std. Dev.
Initial Average
Std. Dev.
Run
Number
1
2
1-2
A-C
1
2
1-2
A-C
3
1
2
1-2
A-C
1
2
1-2
A-C
Drv Forms
Total
Sulfur
0.77
0.76
0.57
0.62
0.68
±.100
1.37
±.0?F
0.83
0.95
0.89
±.085
1.79
1.122
0.63
0.78
0.83
0.80
±.035
3.14
±.050
0.59
0.57
0.58
±.01A
2.06
±.015
Pyritic
0.04
0.06
0.03
0.04
0.04
±.013
0.90
* m 7
0.19
0.19
0.26
0.20
0.21
±.C34
1.42
+ .087
0.07
0.10
0.13
0.12
0.18
0.13
±.034
2.87
±.062
0.13
0.13
0.12
0.12
0.12
±.006
1.42
±.020
f Sulfur. % w/w
Sulfate
0.04
0.05
0.05
0.09
O.OP
:..C?2
0.02
-.017
0.13
0.14
0.09
0.15
0.13
±.026
0.05
±.00
0.15
0.11
0.11
0.11
±.00
0.05
±.00
0.09
0.07
0.08
±.014
0.07
±.00
Organic
0.69
0.65
0.49
0.49
0.58
±.103
0.45
+ .035
0.50
0.69
0.55
±.095
0.32
+ .147
0.41
0.55
0.57
0.56
±.049
0.22
±.080
0.37
0.38
0.38
±.021
0.57
±.025
Drv Proximate Analysis, % w/w
Ash
22.59
22.63
22.61
±.028
26.40
1 +.081
6.25
6.39
6.32
±.099
8.68
i.087
23.85
24.49
24.17
±.453
30.23
±.310
43.44
43.47
43.46
±.021
49.25
±.045
Volatile
Matter
25.17
25.45
25.31
±.198
24.45
±.342
35.49
34.81
35.15
+ .481
35.30
±.180
17.35
17.79
17.57
+ .311
16.18
±.081
22.20
22.06
22.13
±.099
23.19
±.058
Fixed
Carbon
52.24
51.92
52.08
± . 200
49.15
±.423
58.26
58.80
58.53
+ .491
56.02
±.221
58.80
57.72
58.26
±.549
53.59
±.320
34.36
34.47
34.41
+ .101
27.56
±.073
utu/lh
11739
11701
11720
±26.9
11041
±26.8
13922
13845
13884
+54.4
13451
±65.4
11532
11468
11500
±45.3
10550
±52.6
8137
8138
8138
±0.7
7693
±21.0

-------
01
ro
                                                       Table D-4

                                               PYRITIC  SULFUR REMOVAL DATA

                                  MEIGS,  DEAN,  KOPPERSTON,  AND HARRIS NOS.  1  & 2 MINES

Mine, Seam,
and Location
Melgs Mine
Clarion 4A Seam
Melgs County
Ohio
Dean Mine
Dean Seam
Scott County
Tennessee
Kopperston Mine
Campbell Creek Seam
Wyoming County
West Virginia
Harris Nos. 1 & 2
Mines
Eagle and No. 2 Gas
Seams
Boone County
West Virginia

Mesh
100
100


150
150


100
100


100
100


Total
Rxn.
Time
23
23


23
23


13
13


23
23


Leach Changes
Number Time (hrs)
1 9
1 9
Treated Average
Std. Dev.
Initial Average
Std. Dev.
0
0
Treated Average
Std. Dev.
Initial Average
Std. Dev.
0
0
Treated Average
Std. Dev.
Initial Average
Std. Dev.
0
0
Treated Average
Std. Dev.
Initial Average
Std. Dev.

Run
Number
1
2
1-2
A-C
1
2
1-2
A-C
1
2
1-2
A-C
1
2
1-2
A-C

Total
Sulfur
1.97
1.90
1.94
±.049
3.73
±.035
2.08
2.07
2.08
±.007
4.09
±.026
0.63
0.59
0.61
±.028
0.91
±.047
0.77
0.77
0.77
±.00
1.00
±.006
Dry Forms
Pvrltlc
0.20
0.19
0.15
0.14
0.17
±.029
2.19
±.030
0.20
0.13
0.19
0.18
0.17
±.029
2.62
±.087
0.02
0.03
0.02
0.08
0.04
±.029
0.47
t.026
0.02
0.04
0.02
0.10
0.04
±.038
0.49
±.036
if Sulfur. %
Sulfate
0.16
0.13
0.14
±.021
0.06
±.006
0.17
0,15
0.16
±.014
0.15
±.00
0.07
0.08
0.08
±.007
0.03
±.012
0.06
0.07
0.06
± 007
0.03
±.00
w/w
Organic
1.61
1.63
1.63
±.061
1.48
±.046
1.75
1.74
1.75
+ .033
1.32
±.091
0.54
0.46
0.49
±.041
0.41
«.055
0.68
0.64
0.67
+ .039
0.48
+ .036
Dry 1
Ash
20.61
20.16
20.38
+ .318
26.53
±.164
13.72
13.59
13.66
±.092
17.28
+ .272
25.56
25.50
25.53
+ .042
30.15
+ .050
16.33
16.59
16.46
±.184
18.63
+ .056

volatile
Matter
35.03
35.51
35.27
+ .339
34.92
±.467
33.66
34.85
34.26
±.841
36.91
±2.01
27.42
27.96
27.69
±.382
23.89
+ .173
31.60
29.96
30.78
±1.16
26.86
±.224

Fixed
44.36
44.33
44.35
±.465
38.55
±.495
52.62
51.56
52.08
+ .846
48.81
±.2.03
47.02
46.54
46.78
+ .384
45.96
t.180
52.07
53.45
52.76
±1.18
54.51
±.231

btu/lb
11022
11104
11063
±58.0
10246
±7.9
12674
12652
12663
±15.6
12107
±40.0
11339
11341
11340
±1.4
10957
±24.9
12551
12561
12556
±7.1
12414
±38.5

-------
                Table D-5
        PYRITIC SULFUR REMOVAL DATA
NORTH RIVER, HOMESTEAD, KEN, AND STAR MINES

Mine, Sean,
and Location

North River Mine
Corona Seam
Jefferson County

Alabama

Homestead Mine
No. 11 Seam
Ohio County

West Kentucky

Ken 'line
No. 9 Seam
Ohio County

West Kentucky
Star Mine
No. 9 Seam
Hopkins County
West Kentucky

Mesh


100
100




100
100




100
100



150
150


Total
Rxn.
Time

23
23




23
23




23
23



23
23


Leach Changes

Nuraber Time (hrs)

0
0
Treated Average
Std. Dev.
Initial Average
Std. Dev.
1 5.0
1 5.0
Treated Average
Std. Dev.
Initial Average
Std. Dev.
1 5
1 5
Treated Average
Std. Dev.
Initial Average
Std. Dev.
2 5 S 10
2 5 & 10
Treated Average
Std. Dev.
Initial Average
Std. Dev.

Run
Number

1
2
1-2

A-C

1
2
1-2

A-C

1
2
1-2

A-C
1
2
1-2
A-C
Dry Forms of Sulfur, % w/w
Total
Sulfur

0.92
0.94
0.93
'.014
2.06
'.015
2.31
2.45
2.38
.099
4.46
• .oin
2.82
2.75
2.78
-.059
4.83
'.036
2.52
2.39
2.46
-'.092
4.32
'.025

Pyri tic
0.19
0.13
0.15
0.10
0. 14
'.038
1.42
'.026
0.20
0.15
0.24
0.28
0.22
• .056
3.11
• .049
0.28
0.34
0.21
0.27
0.28
1.021
2.85
-.038
0.06
0. 10
0.03
0.06
0.06
.'.029
2.60
-.100

Sulfate

0.09
0.09
0.09
i.OO
0.07
'.00
0.29
0.32
0.30
-.021
0. 10
• .011
0.27
0.24
0.26
'.021
0.26
'.006
0.35
0.33
0.34
-'.014
0.24
'.029

Organic

0.67
0.73
0.70
+ .040
0.57
t.025
1.84
1.87
1.86
'.116
1.25
• .051
2.24
2.27
2.24
^•043
1.72
'.053
2.09
2.02
2.06
±.097
1.50
-'.075
Dry Proximate Analysis, % w/w

Ash

42.68
43.00
42.84
1.226
49.28
' .045
11.40
11.59
11.50
'.134
16.56
'.150
9.46
9.42
9.44
1.028
15.08
'.057
8.68
8.47
8.58
±.148
13.90
Volatile
Matter

23.85
23.62
23.74
i.163
23.19
t.058
36.77
35.08
35.92
* 1 . 20
33.14
'.573
36.62
35.97
36.30
±.460
35.26
'.839
34.92
35.06
34.99
i.099
33.94
Fixed
Carbon

33.47
33.38
33.42
' .279
27.56
±.073
51.83
53.33
52.58
'1.21
50.30
'.592
53.92
54.61
54.26
±.461
49.66
±.841
56.40
56.47
56.43
±.178
52.16

btu/lu

8399
8247
8323
1107.5
7693
•-21.0
12301
12231
12266
'49.5
11935
"19.7
12695
12683
12689
±8.5
12099
132.7
12646
12655
12650
6.4
2308

-------
                                                                             TABLE D-6

                                                                   PYRITIC SULFUR REMOVAL DATA

                                                                            NAVAJO MINE
Mine, Seam
and Location
Navajo Mine
Nos. 6,7,8 Seam
San Juan County
New Mexico

Mesh

100

100

Total
Rxn.
Time

23

6

Leach Changes
Number Time (hrs)

2 5.0, 13.5

1 3
Initial Average
Run
Number

1-3

4
-
Dry .Forms c
Total
Sulfur

0.76

0.61
0.81
Pyr1t1c

0.04

0.03
0.28
F Sulfur. % w/w
Sulfate

0.15

0.12
0.03
Organic

0.57

0.46
0.50
Dry Proximate Analysis. % w/w
Ash

20.53

19.70
25.29
Volatile
Matter

35.82

35.77
35.51
Mxed
Carbon

43.60

44.53
39.40
btu/lb

10033

10353
10050
        Includes Supplemental  Run Data  and  Summary  of Initial  Data from Ref.  2.
tn
•Pk

-------
                   APPENDIX E
               WASHABILITY TABLES
NOTE:  Coal washability results have been
       performed through standard flat and
       sink testing, discussed in Section 4.4
                      155

-------
                    Central  Ohio Coal Co.
          Muskingum Mine -  Meigs  Creek #9  Seam
                    Morgan County,  Ohio
                  Raw Run of  Mine  Coal
       FLOAT  & SINK ANALYSIS (%  w/w DRY BASIS)
        TABLE  E-1.  38.1  mm  X 149y (1V2"  X 100 mesh)
SPECIFIC GRAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
head Sample
Fine"
FRACTION ANALYSIS
"Sulfur
tut. *Ash Total PyHtlc
1.1 3.98 3.49 .68
38.5 9.81 4.23 1.49
43.5 21.19 4.61 2.41
8.4 37.88 6.59 5.48
8.5 61.75 15.12 14.26
CUMULATIVE RECOVERY FLOAT
•Sulfur
*Wt. Msh Total Pyrltle
1.1 3.98 3.49 .68
39.6 9.65 4.21 1.47
83.1 15.69 4.42 1.96
91.5 17.73 4.62 2.28
00.0 21.47 5.51 3.30
22.23 5.49 3.41
27.40 5.27 3.04
CUMULATIVE REJECT SINK
SSSulfur
tut. JAsh Total PyHtlc
100.0 21.47 5.51 3.30
98.9 21.66 6.53 3.33
60.4 29.22 6.36 4.50
16.9 49.89 in. 88 9.90
8.5 61.75 15.12 14.26
   a) 38.1 mm x 149M (1-1/2" x 100 mesn) =  99.0" of Raw Run of Mine Coal  Crushed to ?R.l mm.
   b) 149n x 0 (100 mesii x 0) = 1.0' of Raw Run of Mine Coal Crushed to 3R.1 n«r.

        TABLE  E-2.  9.51 mm  X 149y {3/8" X  100  mesh)
SPECIFIC GRAVITY
Sink Float
1.30
1 . 30 1 . 40
1.40. 1.60
1.60 1.90
1.90
Head Sample
Fineb
FRACTION ANALYSIS
iSulfur
»t. JAjh Total Pyrltle
4.8 8.51 4.19 1.92
48.5 15.13 4.89 2.78
34.6 26.90 5.25 3.25
6.3 36.61 6.11 5.25
5.8 61.00 13.72 13.24
CUMULATIVE RECOVERY FLOAT
'Sulfur
«tt. Msh Total Pyrltle
4.8 8.51 4.19 1.92
53.3 14.53 4.83 2.70
R7.9 19.40 4.99 2.92
94.2 20.55 5.07 3.07
100.0 22.90 5.57 3.66
22.39 5.61 3.41
22.96 5.56 3.28
CUMULATIVE REJECT SINK
"Sulfur
IWt. lAsh Total PyHtlc
100.0 22.90 5.57 3.66
"5.2 23.62 5.64 3.75
46.7 32.45 6.42 4.76
12.1 48.30 9.76 9.08
5.8 61.00 13.72 13.24
a)  9.51 mm x 149« (3/8" x 100 mesn)  = 94.2" nf R,iw Run of nine Coal Crushpd to 1.51 m
b)  149n x 0 (100 rcesn x 0) = 5.8  of Raw Run of (line Coal Crushed to 9.51 pm.

        TABLE  E-3.  1.41  mm X  0  (14 mesh X 0)
SPECIFIC GRAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample
FRACTION ANALYSIS
'Sulfur
»t. lAsh Total PyHtlc
11.5 9. 18 3.46 .82
35.5 12.46 4.38 1.64
32.1 24.39 4.20 2.05
11.5 35.42 5.64 4.04
9.4 57.90 16.74 16.06
CUMULATIVE RECOVERY FLOAT
Sulfur
tut. Msh Total PyHtlc
11.5 9.18 3.46 .82
47.0 11.66 4.15 1.44
79 . 1 1 6 . 82 4.17 1 . 69
90.6 19.18 4.36 1.99
100.0 22.82 5.52 3.31
22.52 5.60 3.40
CUMULATIVE REJECT SINK
'Sulfur
twt. JAsh Total Pyrltle
100.0 22.82 5.52 3.31
R8.5 24.60 5.7" 3.63
53.0 32.73 6.74 4.97
20.9 45.53 10.63 9.45
9.4 57.90 16.74 16.06
a)  1.41 mm x 0 (14 mesh x 0) =  100.0'. of Mine Coal Crushed to  1.41 run.
                              156

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                    Quarto Mining Company
        Powhattan No.  4 Mine -  Pittsburgh No. 8  Seam
                     Monroe  County, Ohio

                    Raw  Run  of Mine Coal

         FLOAT &  SINK  ANALYSIS  (% w/w DRY BASIS)
          TABLE  E-4.   38.1  mm  X 149y C\l/2"  X  100 mesh)
SPECIFIC GRAVITY
Sink Float
1 . JO
1 . JO 1 .10
1.40 I. o()
1 .00 1 . vo
1 . VO
Head Sample3
F1neb
FRACTION ANALYSIS
JSulfur
JWt. JAsh Tottl Pyrltlc
b.5 5.33 2. OH .59
34.9 It). 04 J.Ob 1 .3-j
lo.O 22.10 4.90 3.9b
7.9 34. 3 / -3.99 4.2.0j 3.91 3.02
CUMULATIVE RECOVERY FLOAT
JSulfur
JWt. JAsh Total Pyrltlc
a. 5 -j.33 2. ob .T)
43.4 9.oO 3.OO I .2'.)
09. 4 1 2.9ri 3.5 1 1.95
6/.J 15.49 J.rso 2.25
IOO.O 37.26 . J.o4 2. 70
38.13 3.69 3.65
58.79 3.52 1.46
CUMULATIVE REJECT SINK
JSulfur
JWt. JAsh Total Pyrltlc
100.0 J/.20 3.04 2. 70
"1.5 40.22 3.9-j 2. '19
00.0 5o.4o ->.4n 3.1')
40.6 72.77 4.JI J./v
32. / ;J2.Oo 3.91 3.62
a)  38.1 mm x I49u (IV x 100 mesh) « 98.3* of Raw run of Mine Coal Crushed to 38.1

b)  149p x 0 (100 mesh x 0) - 1.7* of Raw Run of Mine Coal Crushed to 38.1 mm.

SPECIFIC GRAVITY
Sink Float
1 .30
1 . 30 1 . 40
1.40 1.60
1 .00 1 .90
1 .90
Head Sample8
Fine11
TABLE E-5. 9
FRACTION ANALYSIS
tSul fur
JWt. JAsh Total Pyrltlc
22.3 4.33 2.45 .39
25.0 13.H 1 94
100.0 3/9o 3. /'3 2 49
37.33 3.61 2.64
47.33 3.53 2.33
100 mesh)
CUMULATIVE REJECT SINK
JSulfur
JWt. JAsh Total Pyrltlc
100.0 37.95 J./5 2.49
77.7 4/.00 4.12 3.09
52. 1 03. oo 4.45 3.11
39.7 77. IB 4.23 3.^5
33.4 63.06 J.fl-J 3.59
a)  9.51 mm x U9ii_{|'< x 100 mesh) - 94.3* of Raw Run of Mine Coal Crushed to 9.51 am.

b)  H.9V x 0 (100 mesh x 0) = 5.7% of Raw Run of Mine Coal Crushed to 9.51 mm.
         TABLE E-6.   1.41  mm  X 0  (14  mesh  X 0)
SPECIFIC GRAVITY
Sink Float
1.30
1.30 1.40
1 .40 1 .60
1.60 1.90
1 .90
Head Sample*
FRACTION ANALYSIS
JSulfur
JWt. JAsh Total Pyrltlc
14.6 5./0 .2.35 .47
2ti. 7 9.54 2.63 1 .05
15.4 23.91 4.36 j.3/
8.6 51 .71 4.87 4.4rt
32.7 77.41 4.01 3. 96
CUMULATIVE RECOVERY FLOAT
JSulfur
IWt. JAsh Total Pyrltlc
14.0 5.76 2.35 47
43. j tt.27 2.5/ i tVj
53.7 12.J/ 3.04 1 51
O/. S 1 7.4O 3.27 1 89
100. 0 3/.O3 3.71 2 57
37.18 3.90 2.72
CUMULATIVE REJECT SINK
JSulfur
JWt. JAsh Total Pyrltlc
100 O 3/.OJ 3 71 2.57
35 -I 42.37 3 94 2. PJ
56 7 58.99 .1 5ti i.yG
41 3 72.;'/ 4 
-------
                     National Mines Corporation
                  Isabella  Mine,  Pittsburgh Seam
                   Fayette  County, Pennsylvania
                       Raw Run of  Mine Coal
            FLOAT & SINK ANALYSIS (% w/w DRY  BASIS)
             TABLE  E-7.   38.1  m X  149y  OVz" X  100  mesh)
SPECIFIC GRAVITY
Sink "eat
1.30
1.30 1.40
1.1(0 1.60
1.60 1.90
1.90
Head Sample3
Fine*
FRACTION ANALYSIS
(Sulfur
XHt. XAsh Total Pyrltlc
15.7 5.64 -94 .30
26.3 9.75 1.40 -69
10.5 17.87 2. 46 1.41
7.2 34.54 2.24 1.52
40.3 82.74 1.44 1.42
CUMULATIVE RECOVERY FLOAT
XSulfur
IHt. XAsh Total • Pyrltlc
15.7 5.64 .94 .30
42.0 8.21 .23 .54
52.5 10.14 .47 .72
59.7 13.09 -57 .81
100.0 41.16 .52 1.06
40.17 .48 0.95
45.06 2.08 1.44
CUMULATIVE REJECT SINK
XSulfur
XUt. XAsh Total PyHtlc
100.0 41.16 .52 .06
84.3 47.77 .62 .20
58.0 65.01 .72 .43
47.5 75.43 .56 .44
40.3 82.74 .44 .42
 a)  38.1 mm x 149p (1-1/2" x 100 mesh) - 99.6S of Raw Run of Mine Coal Crushed to 38.1 mm
 b)  149ll " 0 (100 mesh x 0) - 0.44 of Raw Run of Mine Crushed to 38.1 mm
             TABLE  E-8.  9.51  mm X  149y  (3/8" X  100 mesh)
SPECIFIC GRAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample3
Fine*-
FRACTION ANALYSIS
(Sulfur
JWt. XA§h Total Pyrltlc
18.6 5.03 .92 .25
24.9 10.02 1.27 .33
10.1 17.85 2.04 1.26
6.9 45.92 2.62 1.80
39.5 82.35 1.63 1.61
CUMULATIVE RECOVERY FLOAT
ISulfur
ttlt. XAsh Total Pyrltlc
18.6 5.03 -92 .25
43.5 7.89 .12 .30
53-6 9.76 .29 .48
60.5 13.89 .44 .63
100.0 40.93 -52 1.02
41.81 .58 1.09
48.27 .55 1.23
CUMULATIVE REJECT SINK
XSulfur
XWt. XAsh Total Pyrltlc
100.0 40.93 1.52 1.02
81.4 49.13 1.65 1.19
56.5 66.37 1.82 1.57
46.4 76.93 1.78 1.64
39.5 82.35 1.63 1.61
 a)  9.51 mm x I49u (3/8" x 100 mesh) - 97-5* of Raw Run of Mine Coal Crushed to 9.51 mm
 b)  I49u x 0 (100 mesh x 0 ) - 2.5t of Raw Run of Mine Coal Crushed to 9.51 mm

              TABLE  E-9.  1.41  mm X 0  (14 mesh  X 0)
SPECIFIC GRAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample3
FRACTION ANALYSIS
XSulfur
»t. XAih Total Pyrltlc
14.7 4.06 .98 .19
26.0 9.17 1.23 .37
12.7 16.01 2.23 .74
9.6 45.73 1.94 1.60
37.0 85.36 1.92 1.68
CUMULATIVE RECOVERY FLOAT
XSulfur
XHt. XAsh Total PyHtlc
14.7 4.06 .98 '.19
40.7 7.32 .14 .30
53.4 9.39 .40 .41
63.0 14.93 .48 .59
100.0 40.99 .64 .99
40.95 .57 0.99
CUMULATIVE REJECT SINK
XSulfur
XWt. XAsh Total PyHtlc
100.0 40.99 1.64 .99
85.3 47.35 1.76 1.13
59.3 64.09 1.99 1.4?
46.6 77.20 1.92 1.66
37.0 85.36 1.92 1.68
a)  1.41 mm x 0 (14 mesh x 0) - 100.0? of Raw run of Mine Coal Crushed to 1.41 mm
                                   158

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                     Mathies  Coal  Company
                Mathies  Mine - Pittsburgh  Seam
               Washington County,  Pennsylvania

                    Raw Run of Mine Coal

         FLOAT &  SINK ANALYSIS  (% w/w  DRY  BASIS)
TABLE E-10.  38.1  mm X  149y
                                                   X  100 mesh)
SPECIFIC SUAVITY
Sink Float
1 .30
I.JO 1.40
1.40 1.60
1.60 1.90
1 .90
Head Sample3
Fineb
FRACTION ANALYSIS
SSulfur
IWt. SAsh ToUl Pyrltlc
29.3 4.32 1.38 .54
23. -J 25.21 2.96 2.35
7.6 32.06 3.06 2.44
3.3 49. b4 2.H3 2.57
36.3 U2.50 . 7b .60
CUMULATIVE RECOVERY FLOAT
SSulfur
Wt. SAsh Total Pyrltlc
29.3 4.32 I.3H .54
52. « 13.62 2. OH 1.35
60.4 15.94 2.21 1 .4d
63.7 1 7.69 2.24 1 .54
1 00.0 41.22 1.70 1.20
41.01 1.59 1.09
36.18 2.18 1.54
CUMULATIVE REJECT SINK
tSulfur
tut. SAsh Total Pyrltlc
100.0 41.22 1.70 1.2
70.7 56.51 1.83 1.47
47.2 72.09 1.27 1.03
39.6 79. 7b .92 .76
36.3 82.50 .75 .60
a)  38.1 rim x 149u (1-1/2" x 100 mesh) = 98.1% of Raw Run of Mine Coal Crushed to 38.1 m.
b)  149p x 0.000 mesh x 0) = 1.9* of Raw Run of Mine Coal Crushed to 38.1 m.



         TABLE E-ll. 9.51 mm X  149y  (3/8M  X  TOO mesh)
SPECIFIC WAVm
Sink Float
1 .30
1 . 30 1 . 40
1.40 1.60
1.00 1.90
1 .90
Head Sample8
Fineb
FRACTION ANALYSIS
SSulfur
at. SAsh ToUl Pyrltlc
23.5 3.38 1.17 .38
20.5 9.66 2.52 1.71
9.6 17.33 4.19 3.52
3.9 26.91 3.20 2.63
42.5 85.78 .85 .73
CUMULATIVE RECOVERY FLOAT
(Sulfur
JWt. »$h Total Pyrltlc
23.5 3.38 1.17 .38
44.0 6.31 1.80 .00
53.6 8.28 2.23 .45
57.5 9.54 2.29 .53
100.0 41.94 1.68 .19
40.82 1.61 .04
41.89 1.79 1.41
CUMULATIVE REJECT SINK
SSulfur
tHt. SAsh Total Pyrltlc
100.0 41.94 1.68 1.19
76.5 53.79 1.84 1.44
56.0 69.95 1.59 1.34
46.4 80.83 1.05 .89
42.5 85.78 .85 .73
a)  9.51 mm x 149^ (3/8" x 100 mesh) = 94.0* of Raw Run of Mine Coal Crushed to 9.51 nm.
b)  149u x 0 (100 mesh x 0) = 6.0% of Raw Run of Mine Coal Crushed to 9.51 mm.
         TABLE  E-12.  1.41  mm  X  0 (14 mesh X  0)
SPECIFIC SRAVin
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Samplea
FRACTION ANALYSIS
tSulfur
Wt. SAsh Total Pyrltlc
23.0 5.45 1.08 .37
22.3 11.86 1.73 .98
11.4 25.20 2.48 1.95
6.9 39.16 2.12 1.75
36.4 85.11 1.20 1.12
CUMULATIVE RECOVERY FLOAT
SSulfur
sut. SAsh Total Pyrltlc
>
23. O 5.45 .08 .37
45.3 8.61 .40 .67
56.7 11.94 .62 .93
63.6 14.89 .67 1.02
100.0 40.45 .50 1.05
40.20 1.56 1.09
CUMULATIVE REJECT SINK
SSulfur
IWt. SAtlt Total Pyrltlc
100.0 40.45 .50 .05
77.0 50.91 .63 .26
54.7 66.83 .58 . >7
43.3 77.79 .35 .22
36.4 85.11 .20 .12
 a) 1.41 mm x 0 (14 mesh x 0) = 100.0% of Raw Run of Mine Coal Crushed to 1.41 ran.
                              159

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 Consolidation Coal  Co., Mountaineer Coal Co.  Dlv.
            Williams  Mine, Pittsburgh Seam
              Marion County, West Virginia

                  Raw Run  of Mine Coal

        FLOAT & SINK ANALYSIS  (% w/w DRY  BASIS)
         TABLE  E-13.   38.1  mm  X 149y (lV2" X  100 mesh)
SPECIFIC GRAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample3
Fineb
FRACTION ANALYSIS
(Sulfur
(Ht. (Ash Total Pyrltlc
55.0 6.18 1.84 .49
31.3 8.52 2.86 1.59
6.5 21.88 6.40 3.78
1.6 34.38 9.04 8.21
5.6 75.84 15.95 15.79
CUMULATIVE RECOVERY FLOAT
iSulfur
(Wt. tAsh Total Pyrltlc
55.0 6.18 1.84 .49
86.3 7.03 2.21 .89
92.8 8.07 2.50 1.09
94.4 8.51 2.61 1.21
100.0 12.29 3.36 2.03
14.01 3.42 2.08
21.69 3.81 2.51
CUMULATIVE REJECT SINK
ISulfur
(Wt. (Ash Total Pyrltlc
100.0 12.29 3.36 2.03
45.0 19.75 5.22 3.91
13.7 45.40 10.61 9.21
7.2 66.63 14.41 14.11
5.6 75.84 15.95 15.79
 a) 38.1 ran x 149u (l-l/2"x ICO mesh)= 97.65; of Raw Run of nine Coal Crushed to 38.1 mm.

 b) 149u x 0 (100 mesh x 0) = 2.456 of Raw Run of Mine Coal Crushed to 38.1 mm.
        TABLE  E-14.   9.51  mm X  149y  (3/8" X  100 mesh)
SPECIFIC GRAVITY
Sink neat
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample3
Fineb
FRACTION ANALYSIS
(Sulfur
(Ht. (Ash Tot«l Pyrltlc
47.4 3.63 1.72 .20
38.2 12.97 3.33 1.89
7.1 24.51 7.41 6.50
1.9 31.46 9.55 8.64
5.4 74.43 14.24 14.13
CUMULATIVE RECOVERY FLOAT
(Sul fur
(Ht. (Ash Total Pyrltlc
47.4 3.63 1.72 .20
85.6 7.80 2.44 .95
92.7 9.08 2.82 1.38
94.6 9.53 2.95 1.52
100.0 13.03 3.56 2.21
12.85 3.41 1.97
17. 30 3.56 2.15
CUMULATIVE REJECT SINK
iSulfur
(Wt. (Ash Total Pyrltlc
100.0 13.03 3.56 2.21
52.6 21.51 5.23 4.01
14.4 44.15 10.25 9.64
7.3 63.25 13.02 12.70
5.4 74.43 14.24 14.13
a)  9.51 mm x 149ii (3/8" x 100 mesh) = 92.0" of Raw Run of Mine Coal Crushed to 9.51 mm.

b) 149  x 0  (100 mesh x 0) = 8.0* of Raw Run of Mine Coal Crushed to 9.51 irm.
        TABLE  E-15.   1.41  mm X  0 (14 mesh  X 0)
SPECIFIC GRAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample8
FRACTION ANALYSIS
(Sulfur
IWt. (Ash Total Pyrltlc
50.3 4.28 1.69 .24
34.1 8.72 2.33 .82
5.7 22.20 5.16 3.94
2.3 38.11 8.99 8.20
7.6 72.74 16.99 15.63
CUMULATIVE RECOVERY FLOAT
(Sulfur
(Ht. (Ash Total Pyrltlc
50.3 4.28 1.69 .24
84.4 fi.07 1.95 .47
90.1 7.09 2.15 .69
92.4 7.87 2.32 .88
100.0 12.80 3.44 2.00
12.59 3.56 2.11
CUMULATIVE REJECT SINK
(Sulfur
IWt. (Ash Total Pyrltlc
100.0 12.80 3.44 2.00
49.7 21.42 5.20 3.78
15.6 49.17 11.49 10.26
9.9 64.69 15.13 13.90
7.6 72.74 16.99 15.63
a) 1.41 mm x 0 (14 mesh x 0) = 100% of Raw Run of Mine Coal Crushed to 1.41
                             160

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              Consolidation  Coal  Company
         Robinson Run  Mine, Pittsburgh Seam
           Harrison County,  West  Virginia

                  Raw  Run of  Mine  Coal

       FLOAT &  SINK  ANALYSIS  (%  w/w  DRY BASIS)
TABLE E-16.   38.1 mm X  149y
                                                  X  100 mesh)
SPECIFIC SUAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head.Sample8
Fine
FRACTIOH ANALYSIS
ISulfur
JWt. XA*h Tot*l PyHtlc
43.7 4.13 2.24 .37
39.8 8.52 3.38 1.62
6.9 18.64 6.69 5.48
1.8 33.24 9.06 8.33
7.8 74.33 15.65 15.52
CUMULATIVE RECOVERY FLOAT
ISulfur
Wt. XAsh Total Pyrltlc
43.7 4.13 2.24 .37
83.5 6.22 2.78 .97
90.4 7.17 3.08 1.31
92.2 7.68 3.20 1.45
100.0 12.88 4.17 2.55
13.36 3.95 2.61
17.21 4.16 2.39
CUMULATIVE REJECT SINK
ISulfur
IWt. lAsh Total PyrUlc
100.0 12.88 4.17 2.55
56.3 19.67 5.67 4.23
16.5 46.56 11.18 10.54
9.6 66.63 14.41 14.17
7.8 74.33 15.65 15.52
 a)  38.1 mm x 149U (1-1/2" x 100 mesh) = 97.OS of Raw Run of Mine Coal Crushed to 38.1 nm.

 b)  149y x 0 (100 mesh x 0) = 3.05J of Raw Run of Mine Coal Crushed to 38.1 mm.
         TABLE E-17.   9.51 mm X 149y  (3/e"  x 10°
SPECIFIC SUAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
HeadbSamplea
Fine
FRACTION AKALYSIS
ISulfur
»t. XAsh Total Pyrltlc
53.7 4.14 2.19 .46
28.8 9.08 3.38 1.40
6.4 16.02 6.40 5.20
2 1 31.74 9.74 8.86
9 0 74.37 16.47 16.40
CUMULATIVE I&COVERY FLOAT
JSulfur
Bit. JAsh Total PyrUlc
53.7 4.14 2.19 .46
82.5 5.86 2.61 .79
88.9 &.60 2.88 1.11
91.0 7.18 3.04 1.28
100.0 13.22 4.25 2.65
13.17 4.37 2.77
17.62 4.11 2.51
CUMULATIVE REJECT SINK
tSulfur
XWt. lAsh Total Pyr1t1c
100.0 13.22 4.25 2.65
46.3 23.76 6.63 5.18
17.5 47.91 11.98 11.40
11.1 66.30 15.20 14.97
9.0 74.37 16.47 16.40
a)  9.51 mm x 149u (3/8" x 100 mesh) = 95.6; of Raw Run of Mine Coal Crushed to 9.51 mm.

b)  149p x 0 (100 mesh x 0 ) = 4.4t of Raw Run of Mine Coal Crushed to 9.51 trni.
         TABLE E-18.   1.41  mm X   0 (14  mesh  X 0)
SPECIFIC GRAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample3
FMCTIOM ANALYSIS
tSulfur
Wt. lAsh Total Pyrltle
54.1 4.62 2.25 .41
27 5 9.43 3.05 1.31
6.9 18.70 6.28 4.71
2.4 35.20 10.30 9.23
9.1 63.85 18.26 17.60
CUMULATIVE RECOVERY FLOAT
JSulfur
%Wt. %Ash Total Pyrltle
54.1 4.62 2.25 .41
81.6 6.24 2.52 .71
88.5 7.21 2.81 1.02
90.9 7.95 3.01 1.24
100.0 13.04 4.40 2.73
13.00 4.18 2.63
CUMULATIVE REJECT SINK
ISul fur
XWt. tAsh Total PyrUlc
100.0 13.04 4.40 2.73
45.9 22.96 6.93 5.46
18.4 43.18 12.73 11.67
11.5 57.87 16.60 15.85
9.1 63.85 18,26 17.60
 a)  1.41 mm x 0 (14 mesh x 0) = lOOi of Raw Run of Mine Coal Crushed to 1.41 mm.
                              161

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                Consolidation  Coal  Company
            Shoemaker Mine, Pittsburgh  Seam
               Marshall Co., West Virginia
                   Raw Run  of  Mine  Coal
         FLOAT & SINK ANALYSIS (%  w/w DRY BASIS)
TABLE E-19.   38.1  mm X  149p
                                                     x 10°
SPECIFIC SUAVITY
Sink Float
1.30
1 . 30 1 . 1(0
1.40 1.60
1.60 1.90
1.90
Head Sample9
Fine6
FRACTION ANALYSIS
XSul fur
at. XAsh Total Pyrltlc
32. « "t.28 2.46 .53
24.8 14.09 3.57 1.83
10.2 18.49 5.86 4.25
3.2 30. 7k 6.85 5.64
29. 4 83.98 5.71 5.61
CUMULATIVE RECOVERY FLOAT
ISulfur
Hit. XAsh Total Pyrltlc
32.4 4.28 2.46 .53
57.2 8.53 2.94 1.09
67.4 10.04 3.38 1.57
70.6 10.98 3-54 1.76
100.0 32.44 4.18 2.89
32.55 4.03 2.73
32.62 3.38 2.53
CUMULATIVE REJECT SINK
XSul fur
XWt. XAsh Total Pyrltlc
100.0 32.44 4.18 2.89
67.6 45.94 5.00 4.02
42.8 64.39 5.83 5.29
32.6 78.75 5.82 5.61
29.4 83.98 5.71 5.61
 a)  38.1 mm x 149u(l-l/2" x  100 mesh) - 97.8% of Raw Run of Mine Coal Crushed to 38.1 mm
 b)  I49v x 0 (100 mesh x 0) - 2.2% of Raw Run of Mine Coal Crushed to 38.1 mm
          TABLE  E-20.   9.51  mm  X 149y (3/8"  X 100 mesh)
SPECIFIC SUAVITY
Sink Float
1-30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample3
Fineb
FRACTION ANALYSIS
XSul fur
XWt. XAsh Total Pyrltlc
26.3 3-73 2.40 .54
28.6 9.08 3.14 1.65
12.2 20.52 5.59 4.04
3.0 29.31 7.29 6.26
29.9 84.73 5.29 5.26
CUMULATIVE RECOVERY FLOAT
SSulfur
m. XAsh Total Pyrltlc
26.3 3.73 2.40 .54
54.9 6.52 2.79 1.12
67.1 9-06 3.30 1.65
70.1 9.93 3-<<7 1.85
100.0 32.29 4.01 2.87
32.96 3-74 2.53
36.35 3.75 2.51
CUMULATIVE REJECT SINK
XSul fur
XWt. XAsh Total Pyrltlc
100.0 32.29 4.01 2.87
73.7 42.49 4.59 3.70
45.1 63.67 5.50 5.00
32.9 79.68 5.47 5.35
29-9 84.73 5.29 5.26
 a) 9-51 mm x I49u  (3/8" x 100 mesh) = 96.5% of Raw Run of Mine Coal Crushed to 9.51 mm
 b) 149u x 0 (100 mesh x 0) -  3.51 of Ran Run of Mine Coal Crushed to 9.51 mm
          TABLE E-21.   1.41  mm X   0 (14  mesh  X 0)
SPECIFIC SUAVITY
Sink FlMt
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample*
FRACTION ANALYSIS
XSul fur
XUt. XAsh Total PyHtlc
23-3 3.49 2.34 .45
28.7 7.50 2.93 1.47
12.8 20.45 5.47 4.00
7.5 43.45 7.08 6.15
27.7 85.44 5.15 5.03
CUMULATIVE RECOVERY FLOAT
XSul fur
XWt. XAsh Total Pyrltlc
23.3 3.49 2.34 !45
52.0 5.70 2.67 1.01
64.8 8.62 3.22 1.60
72.3 12.23 3.62 2.07
100.0 32.51 4.04 2.89
32.46 3.71 2.60
CUMULATIVE REJECT SINK
XSul fur
XWt. XAsh Total Pyrltlc
100.0 32.51 4.04 2.89
76.7 41.32 4.56 3.64
48.0 61.55 5-54 4.93
35.2 76.49 5.56 5.27
27.7 85.44 5.15 5.03
a)  1.41 DOT x 0 (14 mesh x 0) =• IOOS of Raw Run of Mine Coal Crushed to 1.41 urn
                              162

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              Eastern Associated Coal Corp.
           Delmont Mine, Upper Freeport  Seam
           Westmoreland  County, Pennsylvania

                  Raw Run of Mine  Coal

        FLOAT & SINK ANALYSIS (%  w/w DRY BASIS)
TABLE 1-22.   38.1 mm X  149y
                                                   X 100 mesh)
SPECIFIC GRAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample3
Fineb
FRACTION ANALYSIS
ISul fur
Wt. IAjh Total Pyrltlc
37.6 4.85 1.33 .79
18.9 11.82 3.34 2.95
13.1 19.08 6.15 5.60
5.3 27.99 7.66 7.39
25.1 76.69 8.59 8.46
CUMULATIVE RECOVERY FLOAT
ISul fur
»t. lAsh Total Pyrltlc
37.6 4.85 1.33 .79
56.5 7.18 2.00 1.51
69.6 9.42 2.78 2.28
74.9 10.74 3.13 2.64
100.0 27.29 4.50 4.10
26.80 4.37 4.01
16.85 3.63 2.14
CUMULATIVE REJECT SINK
ISul fur
IWt. lAsh Total Pyrltlc
100.0 27.29 4.50 4.10
62.4 40.81 6.41 6.10
43.5 53.41 7.74 7.47
30.4 68.20 8.43 8.27
25.1 76.69 8.59 8.46
a) 38.1 mm x 149u (1-1/2" x 100 mesh) = 97.9% of Raw Run of Mine Coal Crushed to 38.1 m
b) 149p x 0 (iou mesh x 0) = 2.1% of Raw Run of Mine Coal Crushed to 38.1 mm.



         TABLE E-23.   9.51 mm X  149y  (3/e"  X 100  mesh)
SPECIFIC GRAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample3
Fineb
FRACTION ANALYSIS
ISul fur
Wt. lAjh Total Pyrltlc
39.1 4.23 1.09 .62
19.5 14.83 3.44 3.06
11.6 22.62 5.68 5.15
5.0 31.51 7.34 7.06
24.8 72.27 10.29 10.16
CUMULATIVE RECOVERY FLOAT
ISul fur
IHt. lAsh Total Pyrltlc
39.1 4.23 1.09 .62
58.6 7.76 1.87 1.43
70.2 10.21 2.50 2.05
75.2 11.63 2.82 2.38
100.0 26.67 4.67 4.31
26.78 4.59 4.20
21.53 3.31 1.95
CUMULATIVE REJECT SINK
ISul fur
IHt. lAsh Total Pyrltlc
100.0 26.67 4.67 4.31
60.9 41.07 6.98 6.68
41.4 53.44 8.64 8.38
29.8 65.43 9.80 9.64
24.8 72.27 10.29 10.16
a) 9.51 mm x 149u (3/8" x 100 mesh) -- 93.5% of Raw Run of Mine Coal Crushed to 9.51 mm.
b) 149u x 0 (100 mesh  x 0 ) = 6.5% of Raw Run of Mine Coal Crushed to 9.51 mm.



         TABLE E-24.   1.41  mm X  0 (14 mesh  X 0)
SPECIFIC GRAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample3
FRACTION ANALYSIS
ISul fur
Wt. lAsh Total Pyrltlc
40.4 4.48 1.14 .41
20.1 11.22 2.16 1.41
8.1 23.69 4.54 3.66
3.9 37.89 7.15 6.62
27.5 71.59 10.94 10.88
CUMULATIVE RECOVERY FLOAT
ISul fur
Wt. lAsh Total Pyrltlc
40.4 4.48 1.14 .41
60.5 6.72 1.48 .74
68.6 8.72 1.84 1.09
72.5 10.29 2.13 1.38
100.0 27.15 4.55 4.00
27.55 4.38 4.18
CUMULATIVE REJECT SINK
ISul fur
Wt. lAsh Total Pyrltlc
100.0 27.15 4.55 4.00
59.6 42.52 6.86 6.43
39.5 58.44 9.25 8.98
31.4 67.40 10.47 10.35
27.5 71.59 10.94 10.88
 a) 1.41 mm x 0 (14 mesh x 0) =  100% of Raw Run of Mine Coal Crushed to 1.41 mm.
                             163

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                      Tunnel ton Mining Co.
               Marion  Mine  - Upper Freeport Seam
                  Indiana County,  Pennsylvania

                     Raw Run of Mine  Coal

           FLOAT  & SINK ANALYSIS  (%  w/w DRY BASIS)
          TABLE  E-25.   38.1  mm  X 149y  (l1/2"  X 100  mesh)
SPECIFIC GRAVITY
Sink "oat
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample
Fineb
FRACTION ANALYSIS
Bui fur
XHt. XAsh ToUT Pyrltlc
34.5 3.81 .93 .24
26.1 12.46 1.24 .81
9.1 17.77 1.48 1.28
7.0 38.62 1.86 1.50
23.3 76.08 2.56 2.50
CUMULATIVE RECOVERY FLOAT
XSulfur
XHt. XAsh Total Pyrltlc
34.5 3.81 .93 .24
60.6 7.54 .06 .49
69.7 8.87 .12 .59
76.7 11.59 .19 .67
100.0 26.61 .51 1.10
25. 7F .37 0.80
20.53 1.51 0.83
CUMULATIVE REJECT SINK
XSulfur
XUt. XAsh Total Pyrltlc
100.0 26.61 1.51 1.10
65.5 38.62 1.81 1.55
39.4 55.°6 2.19 2.04
30.3 67.43 2.40 2.27
23.3 76.08 2.56 2.50
a)  38.1 mm x 149M (1-1/2" x 100 mesh) = 96.3:: of Raw Run of Mine Coal  Crushp<< tn 28.1 mm.

b)  149c x 0 (100 mesh x 0) = 3.7% of Raw Run of Mine Coal Crushed to 38.1 mm.



          TABLE E-26.   9.51  mm X 149y  (3/8"  X 100  mesh)
SPECIFIC SRAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90 ,
Head Sample
Fine"
FRACTION ANALYSIS
Bui fur
XHt. lAsh Total Pyrltlc
37.8 3.15 .82 .21
23.4 12.84 1.12 .52
7.8 19.53 1.79 1.34
6.6 34.73 2.02 1.63
24.4 74.28 2.68 2.45
CUMULATIVE RECOVERY FLOAT
XSulfur
ait. *Ash Total PyHtlc
37.8 3.15 .82 .21
61.2 6.85 .93 .33
69.0 8.29 1.03 .44
75.6 10.60 1.12 .55
100.0 26.14 1.50 1.01
26.01 1.50 0.97'
25.13 1.57 0.84
CUHULATIVE REJECT SINK
XSulfur
XWt. tAsh Total Pyrltlc
100.0 26.14 1.50 1.01
62.2 40.10 1.91 1.50
38.8 56.55 2.39 2.09
31.0 65.86 2.54 2.28
24.4 74.28 2.68 2.45
    a) 9.51 nm x 149ii (3/8" x 100 mesh) = 94.6': of Raw Run of Mine Coal Crushed to 9.51

    b) 149« x 0 (100 mesh x 0) =  5.4S of Raw Run of Mine Coal Crushed to 9.51 mrc.
           TABLE 1-27.   1.41 mm X  0 (14 mesh X 0)
SPECIFIC SRAVITY
Sink Float
1.30
1 . 30 1 . 40
1.40 1.60
1.60 1.90
1.90
Head Sample
FRACTION ANALYSIS
Bui fur
»t. XAsh Total Pyrltlc
35.8 3.72 .88 .19
22.3 9.24 1.14 .57
12.6 17.86 1.66 1.25
5.6 36.08 1.98 1.67
23.7 77.11 2.76 2.52
CUMULATIVE RECOVERY FLOAT
XSulfur
Mit. XAsh Total Pyrltlc
35.8 3.72 .88 .19
58.1 5.84 .98 .34
70.7 7.98 l.in .50
76.3 10.04 1.17 .58
100.0 25.94 1.54 1.04
25.42 1.50 0.75
CUMULATIVE REJECT SINK
XSulfur
XWt. XAsh Total Pyrltlc
100.0 25.94 1.54 1.04
64.2 38.33 1.91 1.52
41.9 53.81 2.32 2.02
29.3 69.27 2.61 2.36
23.7 77.11 2.76 2.52
 a)  1.41 nm x 0 (14 mesh x 0) = inn.O1:. of Mine Coal Crushed to 1.41 mm.
                                 164

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                        Buckeye Coal Mining  Company
                   Lucas Mine - Middle  Kittanning Seam
                          Columblana County,  Ohio

                              Raw Run of  Mine  Coal

                  FLOAT & SINK ANALYSIS (% w/w DRY BASIS)
                  TABLE E-28.   38.1 mm X 149y  (ll/2"  *  100  mesh)
SPECIFIC SUAVITY
Sink FlNt
1 .30
1 . 30 1 . 40
1.40 1.60
1.60 1.90
1.90
Head Sample3
Fineb
FRACTION ANALYSIS
XSulfur
XWt. XAsh ToUl Pyrltlc
68.5 5.19 .90 .54
23.3 10.22 1.81 1.43
4.2 21.06 3.71 3.62
1.5 38.33 6.24 6.20
2.5 65.69 Id. 66 18.11
CUMULATIVE RECOVERY FLOAT
SSulfur
XMt. JAsh Total Pyrltlc
68.5 5.19 .90 .54
91.8 6.47 1.13 .77
96.0 7.11 1.24 .89
97.5 7.59 1.32 .97
100.0 9.04 1.75 1.40
8.79 1.76 1.33
17.33 2.51 1.74
CUMULATIVE REJECT SINK
XSulfur
XHt. XAsh Total Pyrltlc
100.0 9.04 1.75 1.40
31.5 17.41 3.61 3.27
8.2 37.83 8.73 8.51
4.0 55.43 14.00 13.64
2.5 65.69 18.66 18.11
           a)  38.1 run x 149y (1-1/2" x 100 meshl = 98.5% of Raw Run of Mine Coal Crushed to 38.1
           b)  149p x 0 (100 mesh x 0) = 1.5* of Raw Run of Mine Coal Crushed to 38.1 mm.


                 TABLE E-29.  9.51 mm  X  149y  (Ve"  X   100 mesh)
SPECIFIC SUAVITY
Sink Float
1.30
1 . 30 1 . 40
I.4O 1.60
I.6O 1.90
I.9O
Head Sample3
FRACTION ANALYSIS
f Sulfur
XWt. XAsh ToUl Pyrltlc
70.0 3.32 .69 .13
20.2 11.76 1.76 1.31
3.9 26.92 3.61 3.05
1.4 33. Od 5.59 5.27
4.5 63.00 17.64 17. OO
CUMULATIVE RECOVERY FLOAT
XSulfur
XWt. XAsh Totil Pyrltlc
70.0 3.32 .69 .13
90.2 5.21 .93 .39
94.1 6.11 1.04 .50
95.5 6.51 l.ll .57
100.0 9.05 1.85 1.31
8.88 1.92 1.41
CUMULATIVE REJECT SINK
XSulfur
XUt. XAsh ToUl Pyrltlc
100.0 9.05 1.85 1.31
30.0 22.41 4.56 4.07
9.8 44.37 10.34 9.77
5.9 55.90 14.78 14.22
4.5 63.00 17.64 17.00
Fine
                                           10.34
                                                  1.50
                                                        0.95
           a)  9.51 mm x 149u (3/8" x 100 mesh) = 95.2% of Raw Run of Mine Coal Crushed to 9.51 mm.
           b)  149u x 0 (100 mesh x 0) = 4.8% of Raw Run of Mine Coal Crushed to 9.El mm.


                 TABLE  E-30.   1.41 mm  X  0 (14 mesh X  0)
SPECIFIC SRAVITY
Sink FlMt
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample3
FRACTION ANALYSIS
SSulfur
XHt. XAsh Tot«1 Pyrltlc
62.7 3.12 .53 .17
23.3 7.71 .69 .35
6.2 14.37 1.26 .93
2.2 37.65 2.81 2.64
5.6 65.89 19.91 19.57
CUMULATIVE RECOVERY FLOAT
, XSulfur
XHt. XAsh ToUl Pyrltlc
62.7 3.12 .53 .17
86.0 4.36 .57 .22
92.2 5.04 .62 .21
94.4 5.80 .67 .32
100.0 9.16 1.75 1.40
Q.12 1.81 1.43
CUMULATIVE REJECT SINK
XSulfur
XUt. XAsh Total Pyrltlc
100.0 9.16 1.75 1.40
37.3 19.32 3. BO 3.47
14.0 38.64 «.96 8.65
7.8 57.92 15.09 14.79
5.6 65.89 IV. 91 19.57
           a) 1.41 mm x 0 (14 mesh x 0) = 100.0% of Raw Run of Mine Coal Crushed to 1.41
                                      165

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                Island  Creek  Coal  Company
         Bird No.  3 Mine, Lower  Kittanning  Seam
              Somerset  County, Pennsylvania

                 Raw Run  of Mine  Coal

       FLOAT  & SINK ANALYSIS (%  w/w DRY BASIS)
      TABLE  E-31.   38.1  mm  X 149y (l1/2" X 100 mesh)
SPECIFIC GRAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample3
Fineb
FRACTION ANALYSIS
ISulfur
twt. lAsh Total Pyrltlc
24.5 3.51 .84 .38
34.1 7.75 1.82 1.41
9.7 17.55 2.57 2.12
5.4 38.67 4.43 4.04
26.3 77.83 6.13 5.92
CUMULATIVE RECOVERY FLOAT
ISulfur
I«t. lAsh Total Pyrltlc
24.5 3.51 .84 .38
58.6 5.98 1.41 .98
68.3 7.62 1.57 1.14
73.7 9.90 1.78 1.35
100.0 27.76 2.93 2.55
27.09 2.97 2.55
16.69 2.46 1.78
CUMULATIVE REJECT SINK
SSulfur
tWt. lAsh Total Pyrltlc
100.0 27.76 2.93 2.55
75.5 35.63 3.60 3.26
41.4 58.60 5.07 4.78
31.7 71.16 5.84 5.60
26.3 77.83 6.13 5.92
  a) 38.1 mm x 149U (1-1/2" x 100 mesh) = 97.4% of Raw Run of Mine Coal Crushed to 38.1 ram.

  b) 149t x 0 (100 mesh x 0) = 2.6% of Raw Run of Mine Coal Crushed to 38.1 mm.
      TABLE  E-32.   9.51  mm  X 149y (3/e" X  100 mesh)
SPECIFIC SUAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample9
F1neb
FRACTION ANALYSIS
SSulfur
XWt. XAsh Total Pyrltlc
20.8 2.74 .74 .26
38.8 5.78 1.13 .63
9.6 15.24 2.26 1.30
3.5 30.32 3.52 2.63
27.3 79.14 7.17 7.11
CUMULATIVE RECOVERY FLOAT
ISulfur
IHt. «Ash Total Pyrltlc
20.8 2.74 .74 .26
59.6 4.72 .99 .50
69.2 6.18 1.17 .61
72.7 7.34 1.28 .71
100.0 26.94 2.89 2.46
26.04 3.01 2.57
20.24 2.49 1.89
CUMULATIVE REJECT SINK
ISulfur
JWt. lAsh Total Pyrltlc
100.0 26.94 2.89 2.46
79.2 33.30 3.45 3.03
40.4 59.73 5.69 5.34
30.8 73.59 6.76 6.60
27.3 79.14 7.17 7.11
a) 9.51 fm x 149w (3/8" x 100 mesh) = 96.IS of Raw Run of Mine Coal  Crushed to 9.51 ram.

b) 149u X 0 (100 mesh x 0) = 3.9J of Raw Run of Mine Coal Crushed to 9.51 mm.
      TABLE  E-33.   1.41  mm  X 0  (14 mesh X  0)
SPECIFIC SUAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample3
FRACTION ANALYSIS
SSulfur
»t. IA»h Tot»l Pyrltlc
24.2 3.17 1.06 .26
35.7 7.22 1.33 .77
8.6 18.87 2.61 2.06
3.4 39.97 4.06 3.74
28.1 74.07 6.38 6.29
CUMULATIVE RECOVERY aOAT
ISulfur
I«t. lAsh Total Pyrltlc
24.2 3.17 1.06 .26
59.9 5.58 1.22 .56
68.5 7.25 1.40 .75
71.9 8.80 1.52 .89
100.0 27.14 2.89 2.41
26.98 3.03 2.49
CUMULATIVE REJECT SINK
ISulfur
IHt. lAsh Total Pyrltlc
100.0 27.14 2.89 2.41
75.8 34.79 3.47 3.10
40.1 59.34 5.37 5.17
31.5 70.39 6.13 6.01
28.1 74.07 6.38 6.29
a) 1.41 mm x 0 (14 mesh x 0) = 100% of Raw Run of Mine Coal Crushed to 1.41 mm.
                            166

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             American Electric Power Company
         Martinka Mine,  Lower Kittanning Seam
              Loqan County, West Virginia
                   Raw Run of  Mine  Coal
        FLOAT &  SINK ANALYSIS (%  w/w DRY BASIS)
TABLE E-34.   38.1 mm X  149y
                                                 X  100  mesh)
SPECIFIC GRAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample8
Fineb
FRACTION ANALYSIS
XSulfur
XWt. XAsh Total Pyrltlc
12.0 4.01 .77 .13
23.0 14.11 1.14 .61
16.1 28.84 1.86 1.57
11. S 41.56 1.96 1.73
37.4 81.91 2.51 2.46
CUMULATIVE RECOVERY FLOAT
XSulfur
XWt. XAsh Total Pyrltlc
12.0 4.01 .77 .13
35.0 10.65 1.01 .45
51.1 16.38 1.28 .80
<>2.6 21.01 1.40 .97
100.0 43.78 1.8: 1.53
44.86 1.78 1.64
49.26 2.20 2.02
CUMULATIVE REJECT SINK
ISulfur
XWt. XAsh Total Pyrltlc
100.0 43.78 1.82 1.53
88.0 49.21 1.96 1.72
65.0 61.63 2.25 2.11
48.9 72.42 2.38 2.29
37.4 81.91 2.51 2.46
 a)  38.1 mm x 149p (IV1 x 100 mesh) = 96.5% of Raw Run of Mine Coal Crushed to 38.1 mm
 b)  149u x 0 (100 mesh x 0) = 3.5°. of Raw Run of Mine Coal Crushed to 38.1 mm
        TABLE E-35.   9.51 mm  X 149y (3/8" X  100  mesh)
SPECIFIC GRAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample3
Fineb
FRACTION ANALYSIS
JSulfur
XWt. XAsh Total Pyrltlc
8.2 5.26 .78 .19
21.8 15.04 1 .12 .66
18.5 25.92 1.55 1.23
13.0 42.71 1.60 1.36
38.5 82.13 2.87 2.80
CUMULATIVE RECOVERY FLOAT
XSulfur
XWt. tAsh Total Pyrltlc
8.2 5.26 .78 .19
30.0 12.37 1.03 .53
48.5 17.54 1.23 .80
61.5 22.86 1.31 .92
100.0 45.68 1.91 1.64
46.06 1.88 1.63
48.38 2.11 1.80
CUMULATIVE REJECT SINK
JSulfur
IWt. XAsh Total Pyrltlc
100.0 45.68 1.91 1.64
91.8 49.29 2.01 1.77
70.0 59.95 2.29 2.12
51.5 72.18 2.55 2.44
38.5 82.13 2.87 2.80
a)  9.51'mm x 149u (3/8" x 100 mesh) = 98% of Raw Run of Mine Coal Crushed to 9.51 urn
b)  149u x 0 (100 mesh x 0) =  21e  of Raw Run of Mine Coal Crushed to 9.51 mm

       TABLE  E-36.   1.41  mm X  0 (14 mesh  X  0)
SPECIFIC GRAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample3
FRACTION ANALYSIS
tSuUur
XWt. XAsh Total Pyrltlc
15.8 6.25 .68 .10
18.4 15.32 .72 .32
10.4 26.40 .90 .58
11.9 47.16 1.20 1.06
43.5 79.11 3.46 3.38
CUMULATIVE RECOVERY FLOAT
, JSulfur
m. XAsh Total Pyrltlc
15.8 6.25 .68 .10
34.2 11.13 .70 .22
44.6 14.69 .75 .30
56.5 21.53 .84 .46
100.0 46.58 1.98 1.73
46.18 1.82 1.74
CUMULATIVE REJECT SINK
XSulfur
XWt. XAsh Total Pyrltlc
100.0 46.58 1.98 1.73
84.2 54.14 2.23 2.04
65.8 65.00 2.65 2.52
55.4 72.25 2.97 2.88
43.5 79.11 3.46 3.38
a)  1.41 ram x 0 (14 mesh x 0) " 100% of Raw Run of Mine Coal Crushed to 1.41 mn
                             167

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            American  Electric  Power Company
             Meigs  Mine  - Clarion  4A Seam
                   Meigs   County, Ohio

                 Raw Run of Mine Coal

      FLOAT &  SINK ANALYSIS  (% w/w DRY  BASIS)
      TABLE E-37.   38.1 mm X  149y  C\l/2" X  100  mesh)
SPECIFIC GRAVITY
S1i* Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample8
Fineb
FRACTION ANALYSIS
«Sulfur
Wt. JAsh Total Pyrltlc
37.1 3.50 1.87 .41
29.4 14.76 3.17 1.56
8.7 25.55 4.33 3.18
4.4 39.55 3.89 2.95
20.4 77.75 6.59 5.51
CUMULATIVE RECOVERY FLOAT
tSulfur
IHt. iAsh Total Pyr1t1c
37.1 3.50 1.87 .41
66.5 8.48 2.44 .92
75.2 10.45 2.66 1.18
79.6 12.06 2.73 1.28
100.0 25.46 3.52 2.14
24.62 3.70 1.91
24.60 3.27 1.86
CUMULATIVE REJECT SINK
tSulfur
IWt. IAsh Total PyHtlc
100.0 25.46 3.52 2.14
62.9 38.42 4.49 3.16
33.5 59.18 5.65 4.57
24.8 70.79 6.11 5.06
2(1.4 77.75 6.59 5.51
 a)  38.1 mm x 149u (l-l/2"x!00 mesh) = 96.0? of Raw Run of Mine Coal Crushed to 38.1 mm.

 b) 149M x 0 (100 mesh x 0) = 1.0% of Raw Run of the Mine Coal Crushed to 38.1 mm.
      TABLE E-38.  9.51 mm X  149y  (3/8" X  100  mesh)
SPECIFIC GRAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample8
Fineb
FRACTION ANALYSIS
SSulfur
Wt. SA$h Totil Pyrltlc
34.0 3.71 2.10 .39
32.8 13.13 2.97 1.45
10.0 38.33 4.56 3.36
4.0 40.65 4.56 3.77
19.2 77.19 5.80 5.66
CUMULATIVE RECOVERY FLOAT
SSulfur
Bit. SAsh Total Pyrltlc
34." 3.71 2.10 .39
66.8 8.34 2.53 .91
76.8 10.94 2.79 1.23
80.8 12.41 2. 88 1.36
100.0 24.85 3.44 2.18
25.23 3.63 2.02
30.32 3.29 2.0V
CUMULATIVE REJECT SINK
SSulfur
Bit. IAsh Total Pyrltlc
100.0 24.85 3.44 2.18
66.0 35.74 4.13 3.10
33.2 58.07 5.28 4.74
23.2 70.89 5.59 5.33
19.2 77.19 5.80 5.66
a)  9.9( irri x 149W (3/8" x 100 mesh) - 93.11 of Raw Run of Mine Coal Crushed to 9.51

B)  149u x 0 (100 mesh x 0) = 6.95 of Raw Run of Mine Coal Crushed to 9.51 ran.



      TABLE E-39.  1.41 mm X 0  (14  mesh  X  0)
IKCIF1C OMVITT
Sll* FlMt
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Mod Swple*
FMCT10N MMLYSIS
SSulflir
tMt. Stall Toul Pyrltlc
22.2 3.95 2.05 .23
38.6 11.98 2.66 .79
14.9 18.99 3.63 1.90
7.4 45.79 4.41 3.39
16.9 73.11 S.87 5.25
CUMJIAT1VE ttCOKIH FIOAT
ISulfur
«(t. lAsh Teul Pyrltlc
22.2 3.95 2.05 .23
60.8 9.05 2.44 .59
75.7 11.00 2.67 .84
83.1 14.10 2.83 1.07
100.0 24.07 3.34 1.78
24.52 3.38 1.75
CUMUtATlVt RtJECT SINK
ISulfur
Wt. tAih ToUl Pyrltlc
100.0 24.07 3.34 1.78
77.8 29.82 3.71 2.22
39.2 47.38 4.74 J.63
24.3 .64.79 5.43 4.68
16.9 73.11 5.87 5.25
    i)  1.41 •> x 0 (14 flesh « 0) = 100.Ot of Rav Run of Mine Coal Crushed to 1.41 m.
                            168

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                Royal Dean Coal  Co.,  Inc.
                   Dean Mine,  Dean Seam
                 Scott County* Tennessee
                    Raw Run of Mine Coal
         FLOAT &  SINK ANALYSIS  (55 w/w DRY  BASIS)
         TABLE E-40.   38.1 m X  149y  (H/211 X  100 mesh)
SPECIFIC GRAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head. Sample
Fine"
FRACTION ANALYSIS
XSulfur
XWt. XAsh Total Pyrltle
32.7 4.03 2.44 .48
31.6 8.13 2.88 1.15
13.0 18.53 3.74 2.23
6.8 36.56 5.85 4.93
15.9 71.11 11.02 10.92
CUMULATIVE RECOVERY FLOAT
SSulfur
XWt. XAsh Total Pyrltlc
32.7 4.03 2.44 .48
64.3 6.04 2.66 .81
77.3 8.14 2.84 1.05
84.1 10.44 3.08 1.36
100.0 20.09 4.34 2.88
19.12 4.37 2.75
28.97 3.96 2.51
CUMULATIVE REJECT SINK
XSulfur
XWt. XAsh Total Pyritlc
100.0 20.09 4.34 2.88
67.3 27.89 5.27 4.05
35.7 45.38 7.38 6.61
22.7 60.76 9.47 9.13
15.9 71.11 11.02 10.92
 a) 38.1 mm x 149y (1-1/2" x 100 mesh) = 99.0% of Raw Run of Mine Coal  Crushed to 38.1 mm.
 b) 149p x 0 (100 mesh x 0) = 1.0* of Raw Run of Mine Coal Crushed to 38.1 mm.
        TABLE E-41.   9.51  mm X  149y  (3/8"  X  100 mesh)
SPECIFIC SUAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head. Sample
Fine"
FRACTION ANALYSIS
ISulfur
XWt. XAsh Total Pyrltlc
35.8 4.21 2.30 .46
32.3 13.45 3.20 1.60
15.0 22.62 4.21 3.01
5.7 40.88 6.21 5.40
11.2 69.48 11.44 11.32
CUMULATIVE RECOVERY aOAT
XSulfur
XHt. XAsh Total Pyrltlc
35.8 4.21 2.30 .46
68.1 8.59 2.73 1.00
83.1 11.12 2.99 1.36
88.8 13.03 3.20 1.62
00.0 19.36 4.12 2.71
19.03 4.23 2.68
18.10 2.86 1.99
CUMULATIVE REJECT SINK
XSulfur
XWt. XAsh Total Pyrltle
100.0 19.36 4.12 2.71
64.2 27.80 5.14 3.96
31.9 42.34 7.11 6.35
16.9 59.83 9.68 9.32
11.2 69.48 11.44 11.32
 a)  9.51 mto x 14% (3/8" x 100 mesh) = 95.35! of Raw Run of Mine Coal  Crushed to 9.51 mm.
 b)  149u x 0 (100 mesh x 0) = 4.7% of Raw Run of Mine Coal Crushed to 9.51 mm.

        TABLE  E-42. .1.41  mm X  0 (14 mesh X 0)
SPECIFIC GRAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample
FRACTION ANALYSIS
XSul fur
XWt. XAsh Total Pyrltlc
»2.9 8.91 2.67 .92
>5.3 9.99 3.09 1.25
14.9 22.58 3.71 1.93
5.0 28.68 4.13 2.20
11.9 65.60 12.70 12.24
CUMULATIVE RECOVERY aOAT
XSulfur
XWt. XAsh Total Pyrltlc
42.9 8.91 2.67 .92
PS. 2 9.31 2.83 1.04
83.1 11.69 2.98 1.20
88.1 12.65 3.05 1.26-
100.0 18.95 4.20 2.57
19.00 4.09 2.60
CUMULATIVE REJECT SINK
XSulfur
XWt. XAsh Total Pyrltlc
100.0 18.95 4.20 2.57
57.1 26.50 5.35 3.80
31.8 39.64 7.14 5.83
16.9 54.68 10.16 9.27
11.9 65.60 12.70 12.24
a)  1.41 mm x 0 (14 mesh x 0) = 100.0% of Raw Run of Mine Coal  Crushed to 1.41 mm.
                               169

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                  Eastern Associated Coal  Corp.
             Kopperston   No.  2, Campbell  Creek Seam
                  Wyoming County, West Virginia

                       Raw Run of Mine Coal

            FLOAT & SINK ANALYSIS  (% w/w DRY  BASIS)
           TABLE  E-43.   38.1  mm X  149y  (l1/2" X  100  mesh)
SPECIFIC GRAVITY
Sink Float
1.30
1.30 i.4o
l.liO 1.60
1.60 1.90
1.90
Head Sample3
Fine6
FRACTION ANALYSIS
tSulfur
Wt. IAsh Total PyHtlc
40.2 3.94 .79 .24
20.5 7.11 .88 .31
7.3 15.00 1.23 .63
3.5 34.17 1.74 1.06
28.5 81.06 .98 .95
CUMULATIVE RECOVERY FLOAT
ISulfur
IWt. IAsh Total Pyrltlc
40.2 3.94 .79 .24
60.7 5.01 .82 .26
68.0 6.08 .86 .30
71.5 7.46 .91 .34
100.0 28.43 .93 .51
28.15 .95 .49
28.61 .94 .36
CUMULATIVE REJECT SINK
%Sulfur
IHt. tAsh Total Pyrltlc
100.0 28.43 .93 -51
59.8 44.90 1.02 .70
39-3 64.61 1.09 .90
32.0 75.93 1-06 .96
28.5 81.06 .98 .95
a)    38.1 mm x I49u (1-1/2" x 100 mesh) = 99.5% of Raw Run of Mine Coal Crushed to 38.1 nrn

b)    I49t x 0 (100 mesh x 0) - .5£ of Raw Run of Mine Coal Crushed to 38.1 mm
           TABLE  E-44.   9.51  mm  X 149y  (3/e" X  100 mesh)
SPECIFIC GRAVITY
Sink Heat
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample3
Fineb
FRACTION ANALYSIS
(Sulfur
Oft. tAjh Total Pyrltlc
47.7 3.06 .95 .27
19.5 18.22 1.04 .54
6.0 29.01 1.53 1-14
2.1 37.70 2.29 1.77
24.7 83.01 -92 .76
CUMULATIVE RECOVERY ROAT
ISulfur
Int. IAsh Total Pyrltlc
47.7 3.06 .95 .27
67.2 7.46 .98 .35
73.2 9.23 1.02 .41
75.3 10.02 1.06 .45
100.0 28.05 1.02 .53
27.98 .97 .51
28.89 .91 .39
CUMULATIVE REJECT SINK
tSulfur
int. IAsh Total Pyrltlc
100.0 28.05 1.02 .53
52.3 50.84 1.09 .76
32.8 70.23 1.12 .89
26.8 79.46 1.03 .84
24.7 83.01 .92 .76
a)  9.51 mm x l<49u (3/8" x 100 mesh) - 97. U of Raw Run of Mine Coal Crushed to 9.51 mm

b)  149u x 0 (100 mesh x 0) - 2.9* of Raw Run of Mine Coal Crushed to 9.51 mm
           TABLE  E-45.   1.41mm X  0  (14 mesh X  0)
SPECIFIC 6RAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample3
FRACTION ANALYSIS
tSulfur
»t. lAsh Total PyHtlc
22.9 3.08 .63 -23
32.7 8.14 .75 -21
15.7 19.98 1.09 .52
5.0 42.46 1.48 1.17
23.7 78.48 1.08 1.02
CUMULATIVE RECOVERY FLOAT
JSulfur
m. IAsh Total Pyrltlc
22.9 3.08 .63 .23
55.6 6.06 .70 .22
71.3 9.12 .79 -28
76.3 11.31 .83 -34
100.0 27.23 -89 -50
27.85 -90 .48
CUMULATIVE REJECT SINK
tSulfur
IWt. IAsh Total Pyrltlc
100.0 27.23 .89 -50
77.1 34.40 .97 -58
44.4 53-74 1.13 -86
28.7 72.20 1.15 1.05
23.7 78.48 1.08 1.02
  a)  1.41 mt x 0 (14 lesh x 0) • 1001 of Raw Run of Mine Coal Crushed to 1.41 m
                                 170

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            Eastern Associated Coal  Corp.
    Harris Mines  #1 &  #2, Eagle  & #2  Gas Seam
           Boone County* West Virginia
                  Raw Run of  Mine  Coal
        FLOAT & SINK ANALYSIS (%  w/W DRY BASIS)
        TABLE E-46.   38.1 mm X 149y  (l1/2"  *  100  mesh)
SPECIFIC SUAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample
Fineb
FRACTION ANALYSIS
XSulfur
XUt. XAsh Total Pyrltlc
44.9 2 91 -93 .15
18.6 14.35 1.17 .64
12.4 23.18 1.45 .84
9.1 47.45 1.13 .72
15.0 66.59 .77 .75
CUMULATIVE RECOVERY FLOAT
XSulfur
XWt. XAsh Total Pyrltlc
44.9 2.91 .93 .15
63.5 6.26 1.00 .29
75.9 9.03 1.07 .38
85.0 13.14 1.08 .42
00.0 21.16 1.03 .47
20.95 1.10 .55
14.36 1.07 .40
CUMULATIVE REJECT SINK
tSulfur
XWt. XAsh Total Pyrltlc
100.0 21.16 1.03 .47
55.1 36.03 1.12 .73
36.5 47.07 1.09 .77
24.1 59.36 .91 .74
15.0 66.59 .77 .75
a)  38.1 urn x 149y (1-1/2" x 100 mesh) = 98.8% of Raw Run of Mine Coal  Crushed to 38.1 urn.
b)  149u x 0 (100 mesh x 0) = 1.2% of Raw Run of Mine Coal Crushed to 38.1 mm.
        TABLE E-47.   9.51  mm X  149y  (3/8"  X 100 mesh)
SPECIFIC GRAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample
Fineb
FRACTION ANALYSIS
(Sulfur
XHt. XAsh Total Pyrltlc
44.1 3.75 .84 .23
25.5 15.85 1.28 .69
8.9 27.93 1.38 .72
8.4 35.91 1.49 1.14
13.1 68.23 .83 .71
CUMULATIVE RECOVERY FLOAT
SSulfur
XHt. XAsh Total Pyrltlc
44.1 3.75 .84 .23
69.6 8.18 1.00 .40
78.5 10.42 1.04 .43
86.9 12.89 1.09 .50
00.1 20.14 1.05 .53
19.85 1.01 .50
26.95 1.06 .56
CUMULATIVE REJECT SINK
ISulfur
XWt. XAsh Total Pyrltlc
100.0 20.14 1.05 .53
55.9 33.06 1.22 .77
30.4 47.50 1.17 .83
21.5 55.60 1.09 .88
13.1 68.23 .83 .71
a)  9.51 mfn x 149u (3/8" x 100 mesh) = 98.4% of Raw Run of Mine Coal Crushed to 9.51
b)  149p x 0 (100 mesh x 0) = 1.6? of Raw Run of Mine Coal Crushed to 9.51 mm.
        TABLE E-48.   1.41  mm X  0 (14 mesh X 0)
SPECIFIC SUAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample
FRACTION ANALYSIS
SSulfur
XWt. XAsh Total Pyrltlc
34.7 3.93 .72 .19
28.7 8.27 .93 .30
12.6 21.65 1.16 .62
12.8 40.62 1.20 .71
11.2 67.17 2.07 169
CUMULATIVE RECOVERY FLOAT
' XSulfur
IVt. XAsh Total Pyrltlc
34.7 3.93 .72 .19
63.4 5.89 .82 .24
76.0 8.51 .87 .30
88.8 13.14 .92 .36
00.0 19.19 1.05 .5^
19.47 1.03 .46
CUMULATIVE REJECT SINK
XSulfur
tut. XAsh Total Pyrltlc
100.0 19.19 1.05 .51
65.3 27.30 1.22 .68
36.6 42.21 1.45 .98
24.0 53.01 1.61 1.17
11.2 67.17 2.07 1.69
*
a)  1.41 mm x 0 (14 mesh x 0) = 100.0% of Raw Run of Mine Coal Crushed to 1.41 mm.
                              171

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               Republic Steel  Corporation
              North  River Mine, Corona  Seam
               Jefferson  County, Alabama
                  Raw Run of Mine  Coal
        FLOAT & SINK ANALYSIS (%  w/w DRY BASIS)
TABLE E-49.   38.1  mm X  149y
                                                 X  100 mesh)
SPECIFIC SUAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1 . 60 1 . 90
1.90
riead Sample3
Fine1'
FRACTION ANALYSIS
(Sulfur
XHt. XAsh Total Pyrltlc
10.8 5.16 1.59 .S8
21.5 20. 4S 2.22 1.40
10.3 31.10 2.97 2.66
4.6 42.56 5.08 2.77
52.8 90.14 1.08 .44
CUMULATIVE RECOVERY FLOAT
SSulfur
Wt. XAsh Total Pyrltlc
10.8 5.16 1.59 .88
32.3 15.36 2.01 1.23
42.6 19.16 2.24 1.57
47.2 21.42 2.32 1.69
100.0 57.71 1.67 1.03
55.05 1.62 1.01
52.97 1.78 .88
CUMULATIVE REJECT SINK
XSulfur
XWt. XAsh Total Pyrltlc
100.0 57.71 1.67 1.03
89.2 64.07 1.68 1.05
67.7 77.91 l.SO .94
57.4 86.31 1.24 .63
52.8 90.14 1.08 .44
 a)  38.1 mm x 149t (IV * 100 mesh) = 98.0'. of Raw Run of Mine Coal Crushed to 38.1 mm
 b)  149u x 0 (100 :nesh x 0} = 2.0*. of Raw Run of Mine Coal Crushed to 38.1 mm
       TABLE E-50.   9.51  mm X  149y  (3/e" X  100  mesh)
SPECIFIC SRAYITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample3
Fineb
FRACTION ANALYSIS
XSulfur
XHt. XAsh Total Pyrltlc
14.2 4-40 !-37 -39
19.6 21.51 2.24 1.32
JO 4 28.48 2.73 1.84
5 9 44.27 2.9., 2.18
^g'g 89.03 1.23 .98
CUMULATIVE RECOVERY FLOAT
XSulfur
ttt. XAsh Total Pyrltlc
14.2 4.40 . 1.37 .39
33.8 14.32 1.87 .93
44.: 17.65 2.08 1.14
50.1 30.79 2.18 1.27
100.0 54.84 1.70 • 1.12
53.65 1.70 1.08
57.87 1.56 .93
CUMULATIVE REJECT SINK
XSulfur
XWt. tAsh Total Pyrltlc
100.0 54.84 1.70 1.12
85.8 63.19 1.76 1.24
66.2 75.53 1.62 1.22
55.8 84.30 1.41 1.11
49.9 89.03 1.23 .98
a) 9.51 mm x 149u (3/8" x 100 mesh) = 92.1'. of Raw Run of Mine Coal Crushed to 9.51 mm
b) 149p x 0 (100 mesh x 0) =  ~.9°, of Raw Rim of Mine Coal Crushed to 9.51 mm
       TABLE E-51.   1.41  mm X  0  (14 mesh X  0)
SPECIFIC 6RAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1 . 60 1 . 90
1.90
Head Sample3
' FMCTION ANALYSIS
tSulfur
XWt. XAsh Total PyHtlc
21.3 5.11 1.59 .44
16.2 9.68 2.31 1.08
12.1 22.70 2.60 1.58
11.0 60.32 2.69 1.76
39.4 87.07 1.23 1.12
CUMULATIVE RECOVERY ROAT
XSulfur
XW. XAsh Total Pyrltlc
21.3 5.11 1.59 .44
37.5 7.08 1.90 .72
49.6 10.89 2.07 .93
60.6 19.87 2.18 1.08
100.0 46.34 1.81 I.v09
47.22 1.86 1.16
CUMULATIVE REJECT SINK
XSulfur
XHt. XAsh Total Pyrltlc
100.0 46.34 1.81 1.09
78.7 57.50 1.87 1.27
62.5 69.90 1.75 1.32
50.4 81.23 1.55 1.26
39.4 87.07 1.23 1.12
a)  1.41
         x 0 (14 mesh x 0} = 100', of Raw Run of Mine Coal Crushed to 1.41 mm
                             172

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                          Peabody Coal  Company
                      Homestead  Mine,  No.  11 Seam
                          Ohio County,  Kentucky

                          Raw Run of  Mine  Coal

             FLOAT  & SINK ANALYSIS (% w/w DRY BASIS)
             TABLE  E-52.   38.1  mm  X 149y (1V2"  X  100 mesh)
SPECIFIC GRAVITY
Sink Float
1.30
1 . 30 1 . 40
1.40 1.60
1.60 1.90
1.90
Head Sample8
Finalb
FRACTION ANALYSIS
(Sulfur
(Wt. (Ash Total Pyrltlc
51.7 4.44 2.36 1.07
31.0 11.75 3.30 1.93
8.1 18.69 5.62 4.39
1.6 34.00 8.29 7.94
7-6 73.49 11.65 11.20
CUMULATIVE RECOVERY FLOAT
(Sulfur
JWt. JAsh Total Pyrltlc
51.7 4.44 2.36 1.07
88.7 6.69 2.53 i 30
90.8 8.21 2.97 i 66
92.4 8.65 3.06 1.77
100.0 13.58 3.72 2.49
13.72 3.99 2.71
26.64 2.93 2.17
CUMULATIVE REJECT SINK
(Sulfur
JWt. JAsh Total Pyrltlc
100.0 13.58 3.72 2.49
'•S. 3 23.37 5.17 4.00
17.3 44.18 8.52 7.71
9.2 66.62 11.07 10.63
7-6 73-49 11.65 11.20
a) 38.1 irrn x 149u (1-1/2" x 100 mesh) = 97.3% of Raw Run of Mine Coal Crushed to 38.1

b) I49u x 0 (100 mesh x 0) = 2.7* of Raw Run of Mine Coal  Crushed to 38.1 im.
             TABLE E-53.   9.51  mm  X 149y (3/8" X   100  mesh)
SPECIFIC 6RAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1 . 60 1 . 90
1.90
HeacT Sample3
Flnalb
FRACTION ANALYSIS
SSulfur
Wt. JAsh Total Pyrltlc
48.2 4.25 2.29 1.05
30.8 10.57 3-44 2.17
12.8 24.69 4.80 3.67
1.5 32.27 9.05 8.20
6.7 67.51 12.16 11.90
CUMULATIVE RECOVERY FLOAT
(Sulfur
JWt. JAsh Total Pyrltlc
48.2 4.25 2.29 1.05
79.0 6.71 2.74 1.49
91.8 9.22 3.03 1.79
93.3 9.59 3.12 1.89
100.0 13.47 3.73 2.56
13.78 3.89 2.76
1?.OB 4.22 3 11
CUMULATIVE REJECT SINK
(Sulfur
(Wt. (Ash Total Pyrltlc
100.0 13.47 3.73 2.56
51.8 22.05 5.07 3.97
21.0 38.89 7.45 6.62
8.2 61.06 11.59 11.22
6.7 67.51 12.16 11.90
a)  9.51 mm x lt9w (3/8" x  100 mesh) - 98.0?, of Raw Run of Mine Coal  Crushed to 9.51 mm

b)  149u x 0 (100 mesh x 0) - 2.0* of Raw Run of Mine Coal Crushed to 9.51 mm.
            TABLE E-54.   1.41  mm X  0  (14 mesh X  0)
SPECIFIC SUAVITY
Sink Float
1.30
1.30 1.40
1 . 40 1 . 60
1.60 1.90
1.90
Head Sample3
FRACTION ANALYSIS
SSulfur
Wt. (Ajh Total PyHtlc
48.3 4.70 2.47 .71
25.1 11.61 3.55 2.01
14.8 20.58 4.19 3.19
3.8 40.19 7.60 6.68
8.0 62.85 13-92 13.57
CUMULATIVE RECOVERY FLOAT
(Sulfur
Wt. JAsh Total Pyrltlc
48.3 4.70 2.47 .71
73.4 7.06 2.84 1.15
88.2 9.33 3.07 1.50
92.0 10.61 3.25 1.71
100.0 14.79 4.11 2.66
14.83 4.19 2.73
CUMULATIVE REJECT SINK
(Sulfur
(Wt. (Ash Total Pyrltlc
100.0 14.79 4.11 2.66
51.7 24.21 5.64 4.48
26.6 36.09 7.60 6.81
11.8 55.55 11.88 11.35
8.0 62.85 13.92 13.57
      a)  1.41 mm x 0 (14 mesh x 0) * 100.0* of Raw Run of Mine Coal Crushed to 1.41
                                  173

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                       Peabody Coal  Company
                        Ken Mine,  #9 Seam
                       Ohio County,  Kentucky

                       Raw Run of  Mine  Coal

            FLOAT &  SINK ANALYSIS  (%  w/w DRY BASIS)
TABLE E-55.   38.1  mm  X 149y
                                                     "  X  100 mesh)
SPECIFIC SRAVITY
sit* n»«t
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head.Sample
Fine"
FRACTION ANALYSIS
SSulfur
SWt. SAih ToUl Pyrltlc
37.5 4.51 2.41 .56
41.3 10.28 3.72 1.87
12.8 18.84 5.68 4.10
2.1 29.81 9.53 8.27
6.3 75.51 8.79 8.67
CUMULATIVE RECOVERY FLOAT
SSulfur
SWt. SAsh Total Pyrltlc
37.5 4.51 3.41 .56
78.8 7.53 3.10 1.25
91.6 9.11 3.46 1.65
93.7 9.58 3.59 1.79
100.0 13.73 3.92 2.23
13.78 4.34 2.54
30.32 4.22 2.51
CUMULATIVE REJECT SINK
SSulfur
SWt. SAsh Total Pyrltlc
100.0 13.73 3.92 2.23
62.5 19.26 4.83 3.23
21.2 36.77 6.99 5.87
8.4 64.09 8.97 8.57
6.3 75.51 8.79 8.67
a)  38.1 nm x 149p (1-1/2" x 100 mesh) = 98.4S of Raw Run of Mine Coal Crushed to 38.1 ran.
b)  149p x 0 (100 mesh x 0) = 1.6* of Raw Run of  Mine Coal Crushed to 38.1 mm.



            TABLE E-56.   9.51  mm X 149y  (3/8"  X  100 mesh)
SPECIFIC QMVITV
Sink Heat
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
HeaciSample8
Fin?
FRACTION ANALYSIS
SSulfur
ttt. SAsh Tottl Pyrltlc
32.6 4.29 2.46 .54
45.2 10.34 3.22 1.46
13.7 19.90 4.83 3.24
2.6 29.94 8.45 7.31
5.9 69.69 14.93 14.72
CUMULATIVE RECOVERY FLOAT
SSulfur
S¥t. SAsh ToUl Pyrltlc
32.6 4.29 2.46 .54
77.8 7.80 2.90 1.07
91.5 9.62 3.19 1.40
94.1 10.18 3.34 1.56
100.0 13.69 4.02 2.34
13.66 3.96 2.56
35.05 4.58 2.32
CUMULATIVE REJECT SINK
SSulfur
SWt. SAsh Total Pyrltlc
100.0 13.69 4.02 2.34
67.4 18.23 4.77 3.21
22.2 34.31 7.94 6.77
8.5 57.53 12.95 12.45
5.9 69.69 14.93 14.72
a) 9.51 ran x ]49u (3/8" x 100 mesh) = 96.9% of Raw Run of Mine Coal Crushed to 9.51 nm.
b) 149u x 0 (100 mesh x 0) - 3.1% of Raw Run of Mine Coal Crushed to 9.51 ran.


            TABLE E-57.   1.41  mm  X  0   (14  mesh  X  0)
SPECIFIC GRAVITY
Sink Float
1.30
1 . 30 1 . 40
HO 1.60
1.60 1.90
1.90
Head Sample3
FRACTION ANALYSIS
SSulfur
SWt. SAsh Total Pyrltlc
35.0 4.08 2.59 .64
37.1 8.85 3.27 1.24
17.8 21.32 5.10 3. 43
2.3 32.00 7-46 6.02
7.8 63. 24 15.55 15. 0^
CUMULATIVE RECOVERY FLOAT
SSulfur
SWt. SAsh Total Pyrltlc
35.0 4.03 2.59 .64
77.1 6.53 2.04 .95
89.9 9.46 3.37 1.44
92.2 10.0? 3.47 I.b5
100.0 14.18 4.41 2VM
14.12 4.05 2.51
CUMULATIVE REJECT SINK
SSulfur
SWt. SAsh Total Pyrltlc
WO.O 14.18 'i.4l 2.61
(•5.0 19.61 5.39 3.67
27.9 33.92 8.22 6.90
10. 1 56.13 13.71 13-02
7.8 63.24 15.55 15.09
 a)  1.41 mm x 0 (14 mesh x 0) = I00> of Raw Run of Mine Coal  Crushed to 1.41 mm
                                   174

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                  Peabody Coal  Company
                    Star  Mine,  #9  Seam
                Hopkins  County, Kentucky

                    Raw Run of  Mine Coal

       FLOAT  & SINK ANALYSIS (35 w/w  DRY  BASIS)
TABLE  E-58.   38.1  mm  X 149y
                                                  X  100 mesh)
SPECIFIC GRAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1 . 90 1 . 00
Head Sample3
Fineb
FRACTION ANALYSIS
SSuUur
JWt. JAjh Total Pyrltlc
40.2 4.24 2.13 .82
40.6 9.55 3.30 1.65
9.5 20.43 4.76 4.34
2.0 32.52 6.83 6.50
7.7 67.35 11.01 10.98
CUMULATIVE RECOVERY FLOAT
XSulfur
m. lAsh Total Pyrltlc
40.2 4.24 2.13 .82
80.8 6.91 2.72 1.24
90.3 8.33 2.93 1.56
92.3 8.85 3.02 1.67
100.0 13.36 3.63 2.39
13.95 3.77 2.33
28.32 4.06 2.00
CUMULATIVE REJECT SINK
XSuIfur
*Wt. lAsh Total Pyrltlc
100.0 13.36 3.63 2.39
59.8 19.49 4.64 3.44
19.2 40.51 7.48 7.23
9.7 60.17 10.15 10.06
7.7 67.35 11.01 10.98
  a)  38.1 mm x I49y (1-V * 100 mesh) = 98.K of Raw Run of Mine Coal Crushed to 38.1 mm

  b)  149u x 0 (100 mesh x 0)  = 1.8% of Raw Run of Mine Coal Crushed to 38.1 mm
       TABLE  E-59.   9.51 mm X  149y  (3/8"  X  100  mesh)
SPECIFIC GRAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90 1.00
Head Sample3
f ineb
FRACTION ANALYSIS
SSutfur
SWt. SAsh Total Pyrltlc
40.7 5.92 2-20 .89
41.5 10.83 3.12 1.69
9.6 16.88 4.12 3.44
2.7 30.04 7.18 6.58
5.5 70.97 14.02 13-91
CUMULATIVE RECOVERY FLOAT
tSulfur
tut. JAsh Total Pyrltlc
40.7 5.92 2.20 .89
82.2 8.40 2.66 1.29
91.8 9.29 2.82 1.52
94.5 9.88 2.94 1.66
100.0 13.24 3.55 2.34
13.69 3.65 2.37
25.67 4.30 2.30
CUMULATIVE REJECT SINK
ISulfur
IWt. lAsh Total Pyrltlc
100.0 13.24 3.55 2.34
59.3 IP. 26 4.48 3-33
17.8 35.59 7.64 7.15
8.2 57.49 11.77 11.50
5.5 70.97 14.02 13.91
 a)  9.51 mm x  I49u (3/8" x  100 mesh) = 97.2% of Raw Run of Iline Coal Crushed to 9.51 mm

 b)  I49u x 0 (100 mesh x 0) =  2.8$ of Raw Run of Mine Coal Crushed to 9.51 mm
       TABLE  E-60.   1.41 mm X  0  (14  mesh X  0)
SPECIFIC GRAVITY
Sink Float
1.30
1.30 1.40
1.40 1.60
1.60 1.90
1.90
Head Sample3
FRACTION ANALYSIS
SSuIfur
SWt. JAsh Total Pyrjtlc
41.6 8.31 2.45 1.31
42.4 9.88 3.09 1.45
8.6 19.03 4.32 3.40
2.0 31.02 7.44 6.52
5.4 64.97 16.20 15.70
CUMULATIVE RECOVERY FLOAT
tSulfur
IKt. lAsh Total Pyrltlc
41.6 8.31 2.45 1.31
84.0 9.10 2.77 1.38
92.6 10.02 2.92 1.57
94.6 10.47 3.01 1.67
100.0 13.41 3.72 2.43
CUMULATIVE REJECT SINK
SSuIfur
SWt. SAsh Total Pyrltlc
100.0 13.41 3-72 2.43
58.4 17.05 4.63 3.23
16.0 36.03 8.72 7.94
7.4 55.79 13.83 13.22
5.4 64.97 16.20 15.70
a)  1.41 mm x 0 (14 mesh x 0) * 100% of Raw Run of Mine Coal  Crushed to 1.41 mm
                             175

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               Appendix F
Methods and Trace Element Analysis Data
                  176

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                       COAL TRACE ELEMENT ANALYSIS

F.I  GENERAL INTRODUCTION
     The initial handling of coal samples is  just as  important to the
final result as the analytical procedures and techniques  utilized for the
individual determinations.  To ensure the validity  of the values reported,
the following guidelines must be adhered to:

     c  The composition of all sample handling and  grinding  equipment must
        be considered to prevent possible contamination  of the sample.
        For example, stainless grinding equipment must not be used when Ni
        or Cr are to be determined; similarly, a brass screen should not
        be used for sieving when Cu is one of the elements of interest.
     •  All reagent additions must be kept at a minimum;  blanks must
        always be run concurrently; and where possible,  high purity
        reagents should be used.
     •  Prior to any dissolution, fusion, or ashing that is  to be done  on
        the coal, all glassware should be meticulously cleaned.  A  recom-
        mended cleaning procedure is to first wash  all glassware with soap
        (such as Alconox, Dutch Cleanser, etc.) and hot  water in  order  to
        remove traces of grease and oils.  Then, rinse the glassware with
        deionized or distilled water and place it  in a 50%  (v/v)  nitric
        acid bath and allow to soak for two hours  minimum.  This will
        remove traces of any inorganics that may be left behind  by  the
        soap and water washing.  Remove from the bath, flush thoroughly
        with distilled water, follow with acetone  rinse, and dry  in a  clean
        drying oven at 80°C until dry.  Remove from the oven and  store  in
        a protected area free of contamination.
     •  All elements of interest should be completely dissolved  by  the
        procedure employed.  If not, they must be  identified and appro-
        priate steps must be taken in order to ensure complete  dissolution.
     t  Sample solutions should be maintained at pH 2 or less  to prevent
        precipitation.  Once the pH is adjusted tto tyiis  level,  the sample
        solutions must be transferred immediately to polyethylene

                                    177

-------
        containers to minimize  adsorption1 on  the walls  of  glass  (Reference
        29) and they should be  refrigerated (5-10°C)  if it becomes  necessary
        to store them for any period  of time.
     •  Heating of the solutions  to effect dissolution  should  be kept  at  a
        minimum and closely controlled.   This  is to eliminate  the possible
        loss of volatile elements (notably chlorides  of Sb, Se,  As).
        Because of this possibility of loss,  only  HN03  should  be used  and
        the solutions kept below  the  boiling  point.

F.2  SAMPLE PREPARATION
     To ensure both the homogeneity of the sample  and to expedite the
decomposition of the coal, the  coal should be ground  to pass a 100  mesh
screen in a clean one-quart ball  mill.  Once  the samples have  been  ground
to the required 100 mesh size,  they are spread evenly in large petri
dishes and dried overnight at 50°C (± 10°).  Sample  decomposition is
accomplished using a low temperature  oxygen plasma asher (such as Inter-
national Plasma Corporation Plasma Asher, Model 1001B).  This method was
chosen over high temperature muffle furnace ashing because at high
temperatures, some trace elements may be lost by  volatilization (Reference
9).
     A needle valve assembly is installed on the  purge outlet of the plasma
asher in order to control the purge rate and prevent physical  loss  of the
sample by blowing.  In the standard operating procedure, both gas flow
valves can be initiated simultaneously.  However,  by doing so, a temperature
differential is formed between  the two sample chambers.  To eliminate this
problem, only one gas flow valve  is initiated and adjusted to peak  operating
conditions at a time.  When correct adjustment is  reached, the other gas
valve is initiated and adjusted to start specifications.  To prevent sample
blowing when the vacuum system is started, a tight seal must be maintained
at the chamber door.
     Weigh duplicate 2.0 g samples in acid-cleaned petri  dish covers.
Place the covers and contents into the plasma asher and begin the  ashing
procedure.  Approximately every four hours, open  the console and stir  the
coal sample to expose fresh surface.   Ashing is continued  2-3 days or
until no black particles remain.
                                   178

-------
     Transfer the sample ash to a Parr Instrument Co. Model 4745 combustion
bomb's 24 ml Teflon acid digestion cup by tapping the edges of the petri
dish and allowing the ash to flow through a wide-tip funnel into the cup.
By first tapping the dish, a minimum of ash will escape into the room
atmosphere.  Once the bulk of the ash has been removed from the dish,
transfer the remaining fine particles of ash by repeated distilled water
washings.  To minimize the final volume, keep these washings as small as
feasible.  Six ml of ultra pure concentrated HNC>3 (70% w/w) and 2.5 ml  of
ultra pure concentrated HF (52% w/w) are then added to the digestion cup.
Although Teflon is chemically inert, the surface may contain scratches
after repetitive usage which could retain small amounts of material.  It
is advisable to periodically check the blank by running the HN03-HF directly
in the Teflon bomb.  If excessive background is encountered, the inside
surface should be remachined.
Caution:  HF attacks glass so polyethylene or polypropylene pipets or
graduated cylinders must be used.
     The solution is then placed on an asbestos-covered hot plate at
140°C (±10°) and evaporated without boiling until the final volume is 50%
of the original.  The sample cup is then placed in the bomb and the bomb
assembled.  The bomb is placed in an oven at 130°C (±5°) for a minimum of
four hours.
     Remove the sample from the bomb and cool.  After cooling, filter the
solutions through Whatman #41 filter paper into Nalgene polypropylene
volumetric flasks.  Polypropylene funnels must also  be used.  Rinse with
a small amount of distilled water.  With a small clean rubber policeman,
scrape the Teflon inner liner to remove any adhering ash and rinse  into
filter paper.  When filtering is completed, cap the  volumetric flasks
and transfer the filter paper to platinum crucibles.  Ignite the filter
paper in a muffle furnace at 800°C ± 50°C until no filter  paper ash
remains.  Remove from oven, allow to cool, then add  2 small scoops  of
ultra pure Nagt^.  Ratio of Na2C03 to residue should be 'vlO/l.  Fuse the
ash and Na2C03 over a burner flame until the crucible is cherry red  and
the fusion components are in a molten state.  Allow  to remain at this
condition for 1-2 minutes or until complete fusion has taken place.
                                    179

-------
     Remove from flame and allow to cool, then dissolve the fusion  cake
using a 1:1 HCl/water solution.   Filter into the original  volumetric flask
and repeat washing with the 50%  HC1  until cake has  been completely  dissolved.
Wash filter paper with the same  acid solution and dilute to final  100 ml
volume with distilled water.
     Ultra pure reagents are  used throughout because of their high  purity
and low ash residues.  However,  in many cases reagent grade chemicals
could be used provided a blank or neat sample is run simultaneously with
the unknowns.  This would need to be tested in the  lab, for it depends on
the amount of reagent used, the  reagent contamination level and the
concentration of the element  of  interest in the sample.

F.3  ATOMIC ABSORPTION
     The analysis of the dissolved coal ash samples for the elements Mn,
Cu, Cr, Ni, Sn, Ag, Sb, V, Pb, Cd, Zn, Li, Se, Hg and Be is done by flame
or flameless techniques.  Atomic Absorption Spectroscopy (AAS) as a general
analytical tool is normally considered free of interelement interferences
and because of the large dilutions employed, is usually unresponsive to
matrix changes.  However, trace  elemental analysis  of coal ash does not
follow these general rules because the elements of interest are present in
a very dilute form in a relatively concentrated matrix consisting of the
major inorganic components of the coal ash, and because of the relatively
high concentrations of fluxes and acids needed for the dissolution.  These
relatively high concentrations encountered as well  as the complicated
matrix make  it mandatory for the analyst to be aware of and to investigate
the presence of interferences.  The  types of interferences encountered
are classified into the following three categories  (References 18,22)1
     •  Interelement or chemical interferences - for the most part, these
        interferences, when present, can be eliminated by using a high
        temperature N20-acetylene flame or by addition of suppressants.
     •  Matrix effects - these interferences are physical in nature and
        are due to the large  concentrations of acids and solids in
        solution.  These effects are compensated -for by specially preparing
        the standards to match the expected acid and salt  content of  the
        sample.
                                   180

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     •  Molecular absorption - this type of spectral  interference can be
        particularly troublesome when determining trace  elements in
        solutions of high salt content.   Molecular absorptions predomin-
        ately occur from species such as CaOH or SrO  and result in a
        positive error in the absorption measurement.  The  Jarrell-Ash
        810 AA or equivalent is especially suited for the evaluation and
        elimination of this type of interference.  This  is  accomplished
        by first ascertaining the presence of the interference
        by monitoring a nonabsorbing wavelength near  the wavelength of
        interest on a second channel.  This molecular absorption when
        present is visually recorded on a strip chart recorder concurrently
        with the absorption of the desired element.   The interference is
        then subtracted from the combined signal.
     The solutions prepared as per section F.2 can be analyzed directly by
AAS for Mn, Cu, Cr, Ni, Sn, Ag, Sb, V, Pb, Cd, Zn, Li, Se and Be using the
operating conditions specified in Table F-l.  Background correction must
be used for Cd and in some instances for Mn, Be, Zn,  and Sb.   In all cases,
the standards employed for calibration of the instrument must  contain the
same quantities of HN03-HF, Na2C03 and HC1 used in the preparation of the
samples.

F.3.1  Arsenic Analysis (References  15,16,17,27,28,33)

F.3.1.1  Summary
     A sample of coal is mixed with  MgO and  combusted at 550°C in  a  muffle
furnace.  The residue is transferred to a  125 ml Erlenmeyer flask  and
treated with HC1 and KI.  The arsenic is  then volatilized as arsine,
using SnCl2 and Zn, and absorbed in  a silver diethyldithiocarbamate
pyridine solution.  The quantitative determination is then performed
by comparing the absorbance of  the developed color at 540 nm to standards.

F.3.1.2  Reagents
     •  15% KI - 15 g KI dissolved in  100  ml D.I. water
     •  20% SnCl2 - 20  g SnCl2  dissolved  in  100  ml HC1,  heat slowly to
        effect dissolution
                                    181

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                          Table  F-l.
            ATOMIC ABSORPTION  ANALYTICAL PARAMETERS
Element
Mn


Cu

Cr
Ni
Sn

Ag

Sb

V
Pb





Cd


In


Li

Be
Se
Fe

Ca



Hg

Analytical
X
2795


3247

3579
2320
2246

3281

2176

4408
2833





2288


2139


<70fl

2349
1960
2482

4227



2852

Slit A
4


10

4
2
4

10

4

2
10





4


10


in

10
10
2

10



10

Background
X
2882


3171

3563
2316
2186

3257

2241


2850





2297


2197


6698

2312
1879
2511







Slit A
4


10

4
2
4

10

4


10





4


10


10

10
10








Flame
Conditions
Air-acetylene


Air-acetylene

N.O-acetylene
NpO-acetylene
Hydrogen-air

Air-acetylene-
lean
Air-acetylene-
lean
N-0-acetylene
Air-acetylene-
lean




Air-acetylene-
lean

Air-acetylene-
lean

f.r tv1pw_
lean
N20-acetylene
Hydrogen-argon
Air-acetylene

N,0-acetylene



Air-acetylene

Detection Limit
(ppm)
Based on 2 g
0.15


0.25

0.25
0.5
2.5

0.25

5.0

5.0
1.5





0.15


0.15


0.1

0.025
5.0
2.5

3.5



0.2

Reported
Interferences
SI, and molecular
absorbance by K,
Na, Cr
Ca molecular
adsorption
Ni, Fe, pH
Fe, Cr, Ca mole-
cular adsorption
H2S04, H3P04,
5000 ppm Na
Th, H2S04> HjP04

Cu at 1 000 ppm

H3P04
200 ppm N1, Cr,
Mo, Si gave
slight inter-
ference, P0.=
SO,., formate,
phlhalate
Molecular adsorp-
tion by Ca, Mg,
Na, K and Fe
Ca, Na, K, Mg,
and Fe molecular
absorptions
Sr at 50 pom

None reported
None reported
Molecular
absorbance
Sulfate.
phosphate
aluminum and
silica
Same as for •
calcium
Method of
Interference Removal
Ca at 2000 pnm or use
background correction

Use background correction

N?0 acetylene flame or
addition of 2» NH4C1
Use background correction
or N20 acetylene flame
Keep acid concentration
constant
Keep sample well diluted




Use EOTA





Use background correction


Use backqround correction






Use background correction

Add 11 La or use N-0-
acetylene flame


Add U La

References
15,16,17,18,
22,24,26,35,
36
15,16,18,22,
23,26,35,36
15,17,18,22,
32,35.36
17,18,22,26
36
18,22

18,22

18,22

18,21,22
15,17,18,22,
26,35,36




15,17,18,20,
22,23,26,35

15,16,17,18,
22,23,26,35,
36
18,22

15,18,22,37
18,22
18,22

16,17,18,22



18.22

•  Acidified water -  5  ml  cone. H2$04 in 500 ml water
•  MgO -  Reagent
t  Zn - 40  mesh granular
•  Lead acetate solution -  saturated in water
t  Silver diethyldithiocarbamate, pyridine solution - 5 g in one
   liter of pyridine.   Allow  solution to stand in a covered container
   for 48 hours.   Filter through a Whatman #40 filter and store over
   molecular sieves in  a brown bottle.
                             182

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F.3.1.3  Procedure
     To a porcelain crucible, add 1.0 g sample and 0.1 g MgO, and mix.
To another procelain crucible, add 1.0 g and no sample.   This will  be used
later for the blank.  Place all crucibles into a muffle  furnace and heat
slowly to 550°C and maintain at this temperature for 1-1/2 hours.  Remove
from oven and allow to cool.  Transfer to a wide mouthed Erlenmeyer flask
using three 5 ml rinsings of acidified water.  Before transferring, wet the
sample by slowly rinsing down the sides of the crucible  with the acidified
water.  Repeat until the sample is completely wetted.  Wash crucible with
the acid water solution until an approximate volume of 50 ml is attained.
Repeat, following the same procedure for the blank.
     To all the flasks, add 5.0 ml cone. HC1, 2.0 ml of the 15% KI solution,
and 1.0 ml of the 20% SnCl2 solution.  Allow the solutions to stand for 15
minutes.  At the end of this time, the reaction flasks are connected to a
receiving flask by a tube containing glass wool to which a few drops of a
saturated lead acetate scrubbing solution has been added.  Ten ml of the
silver diethyldithiocarbamate solution is added to the receiving flask and
3 grams granular zinc is added to the reaction flasks.  Connect  the reaction
and receiving flask together in as short a  time as possible to prevent any
arsine gas loss.  After allowing 30 minutes  for complete gas evolution,
remove vessel and mix the solution by bubbling nitrogen through  the solution
to remove any residue that is adhering to the side wall.  Transfer the
absorbing solution to 1 cm quartz cells  and  measure  its absorbance at
540 nm against the blank reagent using a spectrophotometer.

"F.3.1.4  Standard Curve
     Before running As determinations, prepare a  100 ppm As  stock  solution
(10 ml of 1000 ppm As and dilute to 100  ml  with distilled water).  Once
the stock solution is prepared, take 1,  2,  5 and  10  mis of  the  100 ppm
standard, transfer to four 100 ml volumetric flasks  and dilute  to marks
with distilled water.  These 1, 2, 5 and 10 ppm As  solutions are the
working standards.
     Place one gram of MgO in each of  five  ceramic crucibles  and heat  in
a 550°C muffle for 1-1/2 hours.  Remove  and cool,  then  transfer to a
                                    183

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125 ml Erlenmeyer with acidified water.   Pi pet one ml  of each  of the  four
standards into the respective Erlenmeyers and one ml  of distilled water
into a fifth Erlenmeyer for a blank, and proceed according to  the procedure
in F.3.2.3.  Note the following:
     1)  The pyridine - silver diethyldithiocarbamate  solution will
         deteriorate slightly, and if not filtered, will lead  to erratic
         values.
     2)  The type of mesh zinc used appears  to have some bearing on  the
         arsine evolution.  Therefore, only  one bottle should  be designated
         for use and a new calibration curve should be run when another
         bottle is employed.
     3)  Heating the reaction solution facilitates the evolution of  arsine
         and has proved helpful in improving the accuracy of the analysis.

F.3.2  Boron (References 15,16,29,30,33)
F.3.2.1  Summary
     Gently ash the coal at 550°C, then fuse the ash  with Na2C03. After
dissolving the fusion mixture in HC1, the boric acid  is extracted with
2-ethyl-l,3-hexanediol and determined as the rosocyanine complex in  95%
ethanol.   This procedure is applicable  to coals  containing between 1-400
ppm B.

F.3.2.2  Reagents
     •  10 ppm standard boron solution - prepare by appropriate dilution
        of 1000 ppm stock boron solution
     •  2-ethyl-l,3-hexanediol - 10% solution in chloroform
     0  Curcumin reagent - 0.375% (w/v) dissolved in  glacial acetic  acid,
        filtered, and stored in a darkened polyethylene bottle
     •  Ethanol - 95% reagent grade
     •  Sulfuric acid - high purity (Van Waters and Rogers Ultrex grade)
     t  Na2C03 - high purity (Van Waters and Rogers Ultrex grade)
     •  IN HC1 - use high purity acid and distilled water
                                    184

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F.3.2.3  Procedure
     Weigh 1 g coal ± 0.1 mg into a platinum crucible; ash at 550°C for
one hour.  Fuse  residue with 1 g of Na2C03, then dissolve the melt with
IN HC1 and dilute to 100 ml.  Pipet 2 ml of this solution into a  10 ml
Nalgene centrifuge tube and extract, by shaking with 2 ml of 2-ethyl-l,3-
hexanediol in CHC13.  Syringe off the liquid phase, and pi pet 0.5 ml  of
the organic phase into a 50 ml Nalgene volumetric flask.   Add 1 ml  of
curcumin reagent followed by 0.3 ml of cone. H2S04 and allow to react for
15 minutes.  Adjust volume to 50 ml with reagent grade 95% ethanol  and
read absorbance  at 500 nm against 95% ethanol.  Run a reagent blank
concurrently and subtract this absorbance from the sample absorbance.  The
boron concentration of the sample is calculated from a standard curve
using the adjusted sample absorbance reading.

F.3.2.4  Standardization
     Prepare standard solutions containing 0.1, 0.2, 0.5, 1.0, 2.0  and 3.0
ppm boron by appropriate dilution of the 10 ppm standard.  Pipet  2 ml of
prepared standard into a Nalgene centrifuge tube and proceed as per general
procedure.  Note that all apparatus is to be washed with 1:1 aqueous HN03.

F.3.3  Fluoride Analysis (References 9,15,31,34)

F.3.3.1  Summary
     Coal is mixed with benzoic acid, pressed into a pellet and combusted
in a Parr bomb and the combustion gases scrubbed with a dilute caustic
solution.  The pH of the solution is now adjusted to 5.2-5.3, and C02 is
expelled by gentle heating.  The fluoride concentration is then determined
after pH readjustment and addition of a citrate - KN03 buffer solution
using a specific ion electrode procedure.

F.3.3.2  Results
     •  IN NaOH - prepared from high purity reagents
     •  0.5N H2S04 - prepared from high purity reagents
                                    185

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     •  1M  sodium citrate,  0.2M KNOs buffer solution  -  dissolve  294 g of
        citric acid trisodium salt dihydrate and  20  g  of KN03  in  one liter
        of high purity water (pH 6.3)
     0  Fluoride standard -  prepare a series of fluoride standards  in the
        following molar concentrations,  .0005,  .001, .005,  .01,  .05 and
        .10, by dissolving high  purity KF in the  citrate-KN03 buffer.

F.3.3.3  Procedure
     Mix a 1 gram coal sample, ground to pass a 100  mesh screen,  with
approximately 0.25 g benzoic acid (primary standard) and place in a fused
quartz sample holder within  a Parr combustion bomb that  contains  10 ml of
IN NaOH.  The bomb is pressurized to about 28 atmospheres and  then fired.
At leased 15 minutes are allowed to elapse before the  bomb  is  depressurized.
Three approximate 5 ml aliquots  of distilled water are used to rinse the
bomb contents into a 50 ml plastic beaker (plastic-ware  is  used  from this
point on).
     The beaker contents are magnetically stirred with a Teflon  bar while
the pH is adjusted to 5.2-5.5 with 0.5N H2S04.  (The  initial pH before
adjustment will be about 7.0).  The beaker is then placed in a hot water
bath for about 10 minutes, removed, and again stirred to drive off most
of the dissolved C02-  Five  ml of the sodium citrate - KN03  buffer solution
is added to the beaker contents.  The total volume is  adjusted to 50 ml
with distilled water and cooled to room temperature.  At this  time, the
potential is read using a fluoride specific ion electrode vs a saturated
calomel reference electrode.  In some cases, about 10 minutes  are required
for equilibrium to be reached.  Then 1 ml of 0.01M F is added and the
potential of the solution is again read.
     The pH is quite critical for the initial potential reading.  At
5.0-5.5, final results tend  to be low because of F~ complexing with H.
Above 6.5, final results tend to be high because  of interference by OH~
or HCOo' at 1000 to 1 concentration over the F".
                                   186

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     The concentration of fluoride in the coal  sample  is  calculated
using the following formulas:
          F (soln)  =         AF
                         exp (AE/S) - 1

          F (coal)  =    50 x F
Where   AF = change in F cone, due to addition of spike  =  3.8 ppm
        AE = change in potential readings = E2~E^
         S = slope of mv vs In (F~) concentration for the  electrode
             = -22.95
        WB = weight benzoic acid
        FB = F~ content of benzoic acid = 7.15 ppm

F.3.4  Mercury Analysis (References 18,19,22,25,38)

F.3.4.1  Summary of Method
     A coal sample is decomposed by burning in a combustion bomb containing
a dilute nitric acid solution  under 24 atmospheres of oxygen pressure.
After combustion, the bomb washings are  diluted  to a known volume, and
mercury is determined by atomic absorption spectrophotometry using a flame-
less cold vapor technique.

F.3.4.2  Apparatus
     •  Oxygen bomb - Standard 360 ml stainless  steel combustion bomb
        as used for coal calorimetry  (ASTM D  2015).
     •  Combustion crucible -  Vycor or quartz crucible  of proper size
        to fit the bomb sample holder (A.M. Thomas No.  3879-C or
        equivalent).
     •  Firing wire - No.  34  B & S gauge  nickel-chromium alloy wire,
        10 cm length.
                                    187

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        Firing circuit - as  described  in  ASTM D  2015.
        Atomic Absorption Spectrophotometer - Use  mercury  hollow cathode
        lamp and a wavelength  of 253.7 nm.
        Absorption cell  - a  cylindrical tube of  approximate  dimensions
        25 mm I.D. X 125 mm  long, with quartz windows,  and incorporating
        inlet and outlet sidearms to permit introduction and discharge
        of carrier gas.   This  type of  cell  is available commercially  from
        several manufacturers  of atomic absorption equipment, or it may
        be constructed from  readily available materials (Note 1).  In the
        latter case, the cell  should be tested carefully for possible
        leakage after assembly.   The cell is mounted in the  optical path
        of the AA spectrophotometer.
        Mercury reduction vessel - a cylindrical,  flat-bottom cold test
        jar (Fisher No.  13-415 or equivalent), containing  a  glass  or
        polypropylene covered  magnetic stirring  bar, and incorporating  a
        two-hole rubber stopper through which are  passed a gas bubbler
        tube (Note 1) and a  short gas  outlet tube.  The bubbler tube  is
        connected to the carrier gas source, and the outlet tube is
        connected to the absorption cell; all connections  should be  made
        with polypropylene tubing (Note 2).  Calibrate the reduction  vessel
        at the 50 ml mark.
        Magnetic stirrer - for use in  conjunction with the mercury
        reduction vessel.
        Flowmeter - capable of measuring gas flows in  the range of one
        liter  per minute.
Note 1 - A constricted, open gas bubbler tube is preferred over the fritted
         glass dispersion type.  With the latter, there is the possibility
         of mercury retention in the frit, at least if the solution is not
         stirred sufficiently.
Note 2 - There is some evidence that certain materials such as Tygon and
         Teflon can adsorb mercury to a significant extent.  For this
         reason, the use of standard Teflon-covered stirring bars is also
         discouraged.
                                   188

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F.3.4.3  Reagents
     •  Stock mercury solution, approximately 1 gram/liter (1,000 ppm).
        Weigh 1  gram of pure, elemental mercury to the nearest 0.1  mg
        and dissolve in a solution consisting of 150 ml of distilled water
        and 50 ml of concentrated HN03 (sp. gr. 1.42).  Dilute this
        solution to 1000 ml with distilled water.  The final  solution
        contains approximately 1,000 ppm of mercury (record exact
        concentration) in a matrix of 5% (v/v) nitric acid.
     •  Standard mercury solutions - Prepare working standard solutions  of
        mercury  down to 1 ppm by serial dilutions of the 1,000 ppm Hg
        stock solution with 5% HN03.  Such solutions may be assumed to be
        stable for up to one week.  Below 1 ppm Hg, standard solutions
        should be prepared daily and diluted with 5% HN03 and/or distilled
        water as appropriate, so that the final solution matrix is
        approximately 1% HN03.
     •  Nitric acid solution, 10% (v/v) - Dilute 100 ml of concentrated
        HN03 (sp. gr. 1.42) to 1000 ml.
     •  Stannous chloride solution, 10% (w/v) - Dissolve 10 g of
        SnCl2-2H20 in 10 ml of concentrated HC1 (warm the solution if
        necessary to accelerate the dissolution process) and dilute to
        100 ml.  Add a few pieces of metallic tin.
     •  Helium carrier gas - Use Matheson High Purity grade or equivalent.
        The gas may contain a trace amount of mercury, and the use of a
        small amalgamator trap (gold or silver wire coils packed in about
        1 inch of tubing) between the gas cylinder and the flowmeter is
        advisable.

F.3.4.4  Standardization
     Transfer an aliquot of a standard mercury solution containing 0.10
micrograms of mercury to the mercury reduction vessel.  Dilute to 50 ml
with 10% HN03, and add 5 ml of 10% stannous chloride  solution.  Insert
the stopper containing the carrier gas inlet and outlet tubes, and start
the magnetic stirrer.  Stir the solution for one minute, then initiate
                                   189

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helium flow at a rate of one liter per minute (Note 3).   Record the
absorption peak and measure peak height.   Repeat this procedure using
varying amounts of mercury throughout the range of 0.01  to 1.00 micro-
grams.
     Run a blank using all reagents except the standard  mercury solution.
Plot absorption (peak height) against micrograms of mercury present,  after
correcting for the reagent blank, to establish a working curve.

F.3.4.5  Procedure
     Mix 1 g of coal and ^0.25 g of benzoic acid.  Press into a pellet and
place in a fused quartz crucible.  Transfer 10 ml of 10% nitric acid  to
the bomb, place the crucible in the electrode support of the bomb, and
attach the fuse wire.  Assemble the bomb and add oxygen  to a pressure of
24 atmospheres (gauge).  Place the bomb in the calorimeter (a cold water
bath  in a large stainless steel beaker is also satisfactory) and ignite
the sample using appropriate safety precautions ordinarily employed in
bomb calorimetry work.
     After combustion, the bomb should be left undisturbed for 10 minutes
to allow temperature equilibration and the absorption of soluble vapors.
Release the pressure slowly and transfer the contents of the bomb  (and
crucible) to the mercury reduction vessel by washing with  10%  nitric acid
(Note 4).
      Rinse the bomb, electrodes, and crucible thoroughly with  several
small washings of 10% nitric acid, then dilute the contents of the reduc-
tion  vessel with 10% nitric acid to a total volume of 50 ml.  Proceed with
the determination as described under Standardization.   Determine the amount
Note 3 - The optimum flow rate will depend on the size of the absorption
         cell.  Several flow rates should be tried until maximum sensi-
         tivity is obtained.
Note 4 - If there is any question  as to whether the sample has  undergone
         complete oxidation during combustion, add 5% potassium perman-
         ganate solution dropwise  until a pink color persists.
                                    190

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of mercury in micrograms and divide by the sample weight in grams  to
obtain the mercury value in parts per million.
     As the bomb ages, there may be a tendency for mercury to become
trapped in the bomb wall fissures during combustion.  In addition, if the
same bomb is used for normal calorimetry work, there may be a tendency for
mercury to accumulate in the bomb with time.  Consequently, before a
series of mercury determinations is undertaken, several blank determina-
tions should be made by firing benzoic acid pellets (approximately 1 gram)
in place of the coal.  Benzoic acid firings should be repeated until a
stable, consistently low blarvk value is obtained.  This final blank value
is then used to correct the mercury values obtained for subsequent coal
samples (Note 5).

F.4  ANALYSIS RESULTS
     The results of trace element analyses for 18 elements in ten coals
before and after treatment by the Meyers and  float-sink procedures are
presented in Tables F-2 to F-ll.  All analyses were run in duplicate on
both untreated and treated coals in order to  get a  good estimate of
precision of the results and a reliable estimate of the trace element
removal.  These analyses were run on two samples of untreated coal in
order that all sources of error such as sampling, ashing, dissolution,
handling, and final analysis would be included in the  final precision
estimate.  In a similar manner, two samples each of the extracted and
float-sink separated coal samples were each analyzed once for two sets of
two values on the treated coal.
     A standard deviation was then calculated for each  set of results  and
was then used to determine which results should  be  discarded.  A  value
falling outside 2a of the mean was not used.   Discarded values are  in
parentheses in the data tables.  The differences between  the initial
Note 5 - The condition  of  the  interior  of  the  bomb  should  be inspected
         at frequent  intervals.   If  evidence of  significant pitting or
         corrosion  is observed (usually indicated by  erratic mercury
         values for samples  or benzoic  acid blanks) the  bomb should be
         returned to  the manufacturer for  reconditioning.
                                    191

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 average  and  the  final  average value are also presented in the tables.
 The deviations of  the  differences were calculated using Equation 1:
 Also  reported are the calculated % removals.  The standard deviation for
 the amount removed was calculated using Equation 2:
                            /b2     2.1
                            7 ' °a    7 ' °b
In cases where 0(a_b)/a is larger or the same as the value of the % diff-
erence, N.D. is entered in the % Loss column to indicate that any apparent
difference in the initial and final values is not statistically valid.
In all cases where the elrnent was not detected in the starting coal, "Ind"
appears in the PPM Change and % Loss columns.
                                   192

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                                                      Table F-2

                                             TRACE ELEMENT ANALYSIS (PPM)


                              MUSKINGUM MINE, MEIGS CREEK NO.  9 SEAM, MORGAN COUNTY, OHIO
Element
Ag
As
B
Be
Cd
Cr
Cu
F
Hg
Li
Mn
Ni
Pb
Sb
Se
Sn
V
Zn
Individual Values
Raw Coal
1.7 3.5 1.7
2.0 - 1.9
48 - 60
1.7 2.2 2.1
1.5 1.7 (o.i;
121 95 114
14 16 15
116 - 118
0.10 - 0.08
55 53 58
26 24 26
25 33 30
13 11 12
<5 - <5
64 - 54
20 16 10
37 33 28
34 27 30
Treated Coal
Meyers Process
0.7 0.2
-
80 60
2.0 1.7
0.6 0.4
56 47
12 19
165 180
-
58 37
7.7 4.8
21 13
289 144
<5 <5
<1 <1
16 30
38 16
12 13
Float-Sink
<1 <1
2.0 2.0
30 30
2 3
2 2
64 58
20 19
90 78
-
16 15
30 25
47 41
32 32
49 36
-
31 41
37 49
22 20
Average Values
Raw Coal
2.3+1.04
2.0±0.07
54±8.5
2.0±0.26
1.6+0.14
110±13.5
15±1.0
117±1.4
0.09+0.014
55+2,5
25+1.2
29+4.0
12±1.0
<5
59+7.1
15±5.0
33±4.5
30±3.5
Treated Coal
Meyers Process
0.4±0.35
-
70±14.1
1.8+0.21
0.5±0.14
52+6.4
16+4.9
172+10.6
-
48+14.8
6.3+2.1
17±5.7
216+103
<5
<1
23±9.9
27±15.6
12+0.7
Float-Sink
<1
2.0+0
30+0
2.5+.071
2+0
61+4.2
19.5±0.7
84±8.5
- -
16+0.7
28+3.5
44+4.2
32±0
42+9.2
- -
36±7.1
43±8.5
18±3.6
PPM Change
Meyers
Process
1.9+1.1
. -
+16+16.5
0.2±0.33
1.U0.20
58±14.9
+1+5.0
+56+10.7
- -
7±15.0
18.7±2.9
12±7.0
+204+103
Ind
- -
+8+11.1
6+16.2
18+3.6
Float-Sink
>1.3+1
0±0.1
24+8.5
+0.5+0.27
+0.4+0.14
49±14.1
+4.5+1.2
33±8.5
- -
39.5+2.6
+3.0+3.7
+15+5.8
+20+1
>+37
- -
+21+8.7
+10+9.6
12+5.0
% Loss
Meyers
Process
83+17
- -
N.D.
N.D.
67+14
53+8
N.D.
Gain
-
N.D.
75±9
41+21
Gain
Ind
- -
N.D,
N.D.
60±5
Float-Sink
>57±20
N.D.
44+7
Gain
Gain
45±8
Gain
28±7.2
- -
72+1 .8
N.D.
Gain
Gain
Gain
- -
Gain
N.D.
40±14
vo
GO

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                                                      Table F-3
                                             TRACE ELEMENT ANALYSIS  (PPM)
                             MATHIES  MINE,  PITTSBURGH SEAM, WASHINGTON COUNTY,  PENNSYLVANIA
Element
Ag
As
B
Be
Cd
Cr
Cu
F
^3
Li
Mn
Ni
Pb
Sb
Se
Sn
V
Zn
Individual Values
Raw Coal
2.2 2.0 1.2
7.1 - 5.1
48 - 60
2.6 2.7 2.7
0.7 1.1 0.5
114 - 106
31 30 27
222 - 197
0.08 - 0.10
70 60 62
64 73 62
35 35 33
25 17 15
<5 <5 <5
78 69
14 - 10
46 68 65
41 41 40
Treated Coal
Meyers Process
0.2 0.2
1.0 1.0
58 60
1.6 1.9
<0.5 <0.5
53 58
23 20
200 219
-
38 42
5.0 8.4
16 15
<5 10
<5 <5
<1 4
<5 <5
15 33
12 13
Float-Sink
1 1
<.l .3
50 45
3 2
4 4
47 49
20 18
82 94
-
24 28
24 23
46 38
36 30
54 46
-
79 77
14 29
21 26
Average Values
Raw Coal
1.8+0.53
6.1+0.41
54+8.5
2.7+0.06
0.8+0.31
110+5.7
29+2.1
210+17.7
0.09+0.014
64+5.3
66+5.9
34+1.2
19+5.3
<5
.74+6.4
12+2.8
60+11.9
41+0.6
Treated Coal
Meyers Process
0.2+0.0
1.0+0.0
59+1 .4
1.8+0.21
<0.5
56+3.5
22+1 .7
210+13.4
-
40+2.8
6.7+2.4
16+0.7
6+5.3
<5
2+2.8
<5
24+12.7
12+0.7
Float-Sink
1+0
0.18+0.18
48+3.5
2.5+0.71
4+0
48+1.4
19+_1.4
88+_8.5
- -
26+2.8
23.5+0.71
42+5.7
33+4.2
50+_5.7
- -
78+1.4
22+10.6
24+3.5
PPM Change
Meyers
Process
1.6+0.53
5.1+0.41
5.0+8.6
0.9+0.22
>.3+0.3
54+6.7
7+2.7
0+22.2
- -
24+6.0
59+6.4
18+1.4
13+7.5
Ind
_. _
>7+2.8
36+17.4
29+0.9
Float-Sink
0.8+0.53
5.9+0.45
6 +9. 2
0.2+0.71
+3.2+0.31
.62+5.9
10+2.5
122+19.6
- -
38+6.0
43+5.9
+8+5.8
+14+6.6
>45+5.7
- -
+66+3.1
38+15.9
21 + .9
% Loss
Meyers
Process
89+3
84+1
N.D.
33+8
>38+24
49+4
24+8
N.D.
- -
38+7
90+4
53+3
68+30
Ind
_ _
>58+10
60+23
71+2
Float-Sink
44+16
97+3
N.D.
N.D.
Gain
56+3
34+7
58+5
- -
59+6
64+3
N.D.
Gain
Gain
— ._
Gain
63+T9
41+9
IO

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                                                       Table F-4

                                              TRACE ELEMENT ANALYSIS (PPM)


                          ROBINSON RUN MINE, PITTSBURGH SEAM, HARRISON COUNTY, WEST VIRGINIA
Element
Ag
As
B
Be
Cd
Cr
Cu
F
US
Li
Mn
Ni
Pb
Sb
Se
Sn
V
Zn
Individual Values
Raw Coal
1.5 1.7
P. 2 5.6
60 60
1.0 n.3
l.fi 2.1
102 98
10 10
114 88
0.13 0.14
15 9
41 42
26 27
13 12
20 18
40 58
15 <5
28 28
32 28
Treated Coal
Meyers Process
1.5 1.0
<0.3 <0.3
75 95
0.7 1.3
1.6 0.9
37 37
17 21
68 94
-
8 8
8.1 6.2
20 16
20 17
4 2
22 13
<5 <5
2 7
11 10
Float-Sink
1 1
1 1
60 60
<0.5 <0.5
3 3
29 32
16 13
113 82
-
5 5
24 23
39 29
23 21
44 32
-
68 91
<5 7
21 14
Average Values
Raw Coal
1.6+0.14
5.9+0.42
60+0
0.6+0.49
1.8+0.35
100+2.8
10+0
100+18.4
0.14+0.007
12+4.2
42+0.7
26+0.7
12+0.7
mi. 4
.49+12.7
8
28+0
30+2.8
Treated Coal
Meyers Process
1.2+2.35 '
<0.3
85+14.1
1.6+0.42
1.2+0.49
37+0
19+2.8
81+18.4
- -
8+0
7.1+1.3
18+2.8
18+2.1
3+1.4
18+6.4
<5
4+3.5
16+0.7
Float-Sink
1+0
1+0
60+0
<0.5
3+0
30+2.1
14+2.1
98+22
- -
5+0
24+0.7
34+7.1
22+J.4
38+8.5
- -
80+16.2
5+3.2
18+5.0
PPM Change
Meyers
Process
0.4+0.38
>5.6+0.4
+15+14.1
+0.4+0.65
0.6+0.60
63+2.8
+9+2.8
19+26.0
- -
4+4.2
35+1.5
8+2.9
+6+2.2
16+1.9
31+J4.2
Ind
24±3-5
14+2.9
Float-Sink
0.6+0.14
4.9+0.42
0+0
>0. 1+0.49
+1.2+0.35
70+3.5
+4+2.1
2+29
- -
7+4.2
18+1.0
+8+7.1
+10+1.6
+18+8.6
- -
>38
23+3.2
12+.5.7
I Loss
Meyers
Process
N.D.
>95+_l
N.D.
N.D.
N.D.
63+1
Gain
N.D.
-
33+23
83+3
31+1
Gain
84+7
-
Ind
86+12
47+5
Float-Sink
38+5
83+1
N.D.
N.D.
Gain
70+2
Gain
N.D.
-
58+J5
43+2
N.D.
Gain
Gain
-
Gain
82+>l
40+18
vo
tn

-------
                                                      Table  F-5

                                             TRACE  ELEMENT ANALYSIS  (PPM)


                         POWHATTAN NO. 4 MINE, PITTSBURGH NO.  8  SEAM,  MONROE  COUNTY, OHIO
Element
Ag
As
b
Se
Cd
Cr
Cu
f
Hg
Li
«n
Ni
Pb
Sb
Se
Sn
V
Zn
Individual Values
Raw Coal
0.7 1.0
A. 6 4.0
65 fin
3.6 3.0
1.1 1.4
130 143
24 26
281 282
0.07 0.07
53 51
56 58
3* 38
23 18
<1 7
53 54
<5 <5
56 65
40 39
Treated Coat
Meyers Process
2.0 2.0
-
87 87
2.3 2.3
1.0 0.5
82 86
31 19
219 216
-
48 46
16 16
32 22
225 215
2 <5
6 27
23 47
63 59
26 16
Float-Sink
1.0 0.5
2 2
50 50
1 3
4 2
•61 62
23 18
115 118
-
16 18
30 28
48 26
40 26
45 25
_
49 38
42 40
24 22

Raw Coal
0.8+0.21
4.3+0.42
62+3.5
3. 3+0; 42
1.2+0.21
141+2.8
25+0.4
282+0.7
0.07+0.00
52+1 .4
57+1.4
37+J.4
20+3.5
<6
54+0.7
<5
60+6.4
40+0.7
Average Values
Treated Coal
Meyers Process
2.0+0.00
-
87+0.1
2.3+0.0
0.8+0.35
84+2.8
25+8.5
218+2.1
-
47j+1.4
16+9
27+7.1
220+7.0
<1.5
16+14,9
35+17.0
61+2.8
21 +.7.1
Float-Sink
0.8+0.35
-
50+_1
2+1.4
3^1 A
62+0.7
20+3.5
116+2.1
- -
17+1.4
29+1.4
37+J5.6
33+9.9
35+14.1
- -
44+7.8
41+J.4
23+1.4
PPM Change
Meyers
Process
+1.2+0.21
-
+25+3.5
1+0.42
+1.8+1.4.
57+4.0
0+8.6
64+2.2
-
5+2.0
41+1 .4
10+7.2
+200+7.8
Ind
- -
>+30
+1+7.0
19+7.1
Float-Sink
0+0.41
—
12+3.6
1.3+1.5
0.4+0.41
79+2.9
5+3.8
166+2.2
- -
35+2.0
20+2.0
0+15.6
+13+10.5
>+30
- -
>+39
19+6.6
17+1.6
% Loss
Meyers
Process
Gain
-
Gain
30+9
N.D.
40+2
N.D.
23+1
-
10+4
72+1
27+19
Gain
Ind
-
Gain
N.D.
48+18
Float-Sink
N.D.
-
19+5
N.O.
Gain
56+1
20+15
59+.1
-
67+3
49+.S
N.D.
N.D.
Gain
-
Gain
32+8
42+4
vo
o>

-------
                                                     Table F-6
                                            TRACE ELEMENT ANALYSIS  (PPM)
                         DELMONT MINE, UPPER FREEPORT SEAM, WESTMORELAND  COUNTY, PENNSYLVANIA
Element
Ag
As
B
Be
Cd
Cr
Cu
F
Hg
Li
Mn
Hi
Pb
St>
Se
Sn
V
Zn
Individual Values
Raw Coal
3.0 2.2
At) 41
15 20
4.0 4.3
1.7 2.0
lAfi 141
20 21
125 137
<0.2 <0.2
24 24
94 94
6fi 70
31 31
11 21
2fi 24
16 23
41 40
7fi 76
Treated Coal
Meyers Process
2.8 5.9
1 1
15 27
3.6 3.4
1.3 1.0'
75 87
20 22
126 131
-
23 24
10 12
35 45
27 47
4 5
<1 <1
9 21
46 48
35 30
Float-Sink
1 1
12 10
5 5
2 2
3 3
50 54
11 11
55 54
-
9 10
35 35
21 22
18 17
14 15
-
34 38
14 11
63 65
Average Values
Raw Coal •
2.6+0.57
40+0.7
18+3.5
4.2+0.21
1.8+0.21
144+3.5
20+0.7
131+8.5
<0.2
24+0
94+0
68+2.8
31+0
16+7.1
.25+1.4
20+5.0
40+0.7
76+0
Treated Coal
Meyers Process
4.4+2.19
1+0
21+8.5
3.5+0.14
1.2+0.21
81+8.5
21+1.4
128+3.5
-
24+0.7
11+1.4
40+7.1
37+14.1
4+0.7
<1
15+8.5
47+1.4
32+3.5
Float-Sink
1+0
11+0.7
5+0
2+0
3+0
52+1.4
11+0
54+0.7
- -
10+0.7
3.5+0
22+0.7
18+1.4
1.4+0.7
-
36+2.8
12+2.1
64+J.4
PPM Change
Meyers
Process
+ 1.8+2.3
39+0.7
+3+9.2
0.7+0.25
0.6+0.30
63+9.2
+1+1.6
3+9.2
- -
0+0.7
83+1.4
28+7.6
+6+14.1
12+7.1
- -
5+9.9
+7+1.6
44+3.5
Float-Sink
1.6+0.57
29+1.0
13+3.5
2+0.21
+1.2+0.21
92+3.8
9+0.7
77+8.5
- -
14+0.7
90+0
46+2.9
13+1.4
15+7.1
- -
+16+5.7
+16+5.7
12+1.4
% Loss
Meyers
Process
N.D.
98+1
N.D.
17+5
33+.14
44+6
N.D.
N.D.
-
N.D.
88il
41+1
N.D. •
75±12
- -
N.D.
Gain
58+5
Float-Sink
62+8
73+2
72+5
52+2
Gain
64+1
45+2
59+3
-
58+3
96+1
68+2
42+5
91+6
-
Gain
Gain
16+2
VO

-------
                                                       Table F-7
                                             TRACE  ELEMENT ANALYSIS (PPM)

                            MARION MINE, UPPER  FREEPORT SEAM,  INDIANA COUNTY, PENNSYLVANIA
Element
Ag
As
a
Be
Cd
Cr
Cu
F
Mg
Li
Mn
Ni
Pb
Sb
Se
Sn
V
Zn
Individual Values
Raw Coal
1.5 1.5
9.5 10.0
5.0 14.9
2.1 2.3
1.5 1.5
78 75
39 38
160 150
0.05 0.06
76 75
24 26
24 22
15 15
7 <5
50 30
5 <5
62 46
36 33
Treated Coal
Meyers Process
<1 <1
<.3 <.3
5.0 14.9
2.0 2.6
<0.5 <0.5
40 35
19 19
136 159
-
63 62
71 80
34 29
14 14
<5 <5
<5 <5
23 7
68 70
n 12
Float-Sink
<1 <:!
8 7
10 10
1 1
2 2
49 46
21 24
78 82
-
27 27
21 19
47 43
32 36
47 55
-
39 47
54 50
21 24



1.5+0.0
9.8+0.35
10+7.0
2.2+OJ4
1.5+0.0
76+2.1
38+0.7
155+7.1
0.06+0.014
76+0.7
25+1.4
23+J.4
15+0
<6
• _ ~
<5
54+11.3
34+2.1
Average Values
Treated Coal
Meyers Process
<1
<0.3
10+7.0
2.3+0.42
<0.5
38+3.4
19+0
148+16.3
-
62+0.7
7.6+0.64
32+3.5
14+0
<5
_ -
15+11.3
69+1.4
12+1.4
Float-Sink
<1
8+0.7
10+0.7
1+0
2+0
48+2.1
22+2.1
80+2.8
- -
27+0
20+1 . 4
45+2.8
34+2.8
51+5.7
_ _
43+5.7
52+2.8
22+2.1
PPM Change
Meyers
Process
>0.5
>9.5
0+10
+0.1+0.44
>1.0
38+4.0
19+0.7
7+17.8
- -
14+J.O
17.4+1.5
+9+3.8.
1+0
Ind
— —
>+io+n
+15+11.4
22+2.5
Float-Sink
>0.5
1.8+_.78
0+7
1.2+0.14
+.5+0
28+3.0
16+2.2
75+7.6
. .
49+0.7
5+2.0
+22+3.1
19+2.8
>45
_
>+38+_6
2+J1.6
12+3.0
* Loss
Meyers
Process
>33
97+4
N.D.
N.D.
>67
50+,5
50+1
N.D.
-
18+1
70+3
Gain
N.D.
Ind
_
Gain
Gain
65+5
Float-Sink
>33
18+8
N.D.
54+3
N.D.
37+3
42+6
48+3
-
64+1
20+^7
Gain
Gain
Gain
_
Gain
N.D.
35+.7
VO
CX5

-------
                                                      Table F-8

                                             TRACE ELEMENT ANALYSIS (PPM)


                             LUCAS MINE, MIDDLE KITTANNING SEAM, COLUMBIANA COUNTY, OHIO
Element
Ag
As
b
Ee
Cd
Cr
Cii
F
Hg
Li
,'ln
N i
Pb
Sb
Sc
Sn
V
Zn
Individual Values
Raw Coal
2.0 2.0
72 75
20 20
3.6 3.9
1.5 1.4
53 52
13 13
63 67
-0.1 .-0.1
« R
17 13
35 35
IB 17
••5 <5
<5 16
5 16
11 9
ifi 55
Treated Coal
".eyers Process
2.1 2.1
8.5 12.9
20 25
3.6 3.7
1.9 1.0
26 28
16 17
56 59
-
5 6
7.7 5.4
33 21
18 14
6 6
2 3
•:5 8
19 15
14 16
Float-Sink
1 <1
14 15
20 20
3 3
3 3
'28 26
fi 7
43 41
-
4 5
10 9
30 20
27 19
7 5
-
23 14
5 12
25 33
Average Values
Raw Coal
2.0+0.0
73.5+2.1
20+0
3.8+0:21
1.4+0.07
52+0 . 7
13+0
65+2.8
-..1
8+0
15+2.8
35+0
18+0.7
-5
8+8.0
10+7.8
12+3.5
50+6.4
Traated Coal
Beyers Process
2.1+0.0
10.7+3.1
22+3.5
3.6+0.07
1,4+0.64
27+1.4
16+0.7
58+2.1
- -
6+0.7
6.6+1.63
27+8.5
16+2.8
6j_0
2+1.4
5+3.9
17+2.8
15+1.4
Float-Sink
<1
14+0.7
20+0
3+0
2+0 .7
27+J.4
8+0.7
42+1.4
- -
4+0.7
10+0.7
25+7.1
23+5.6
6+1.4
- -
18+6.4
10+5.0
29+5.6
PPM Change
heyers
Process
+0.1+0
60+2 . 2
+2+3.5
0.2+0.22
0.0+0.64
25+;. 6
+3+0.7
7+3.5
- -
2+0.7
8.4+3.2
8+8.5
2+2.9
>5
6+_8.1
5+8.8
+5+4.5
35+6.6
Float-Sink
>1
60+2.2
0+0
0.8+0.21
+0.6+0.7
25+1.6
5+0.7
23+3.1
- -
4+0.7
5+2.9
10+7.1
+5+_5.6
>5
- -
+8+10.1
2+_6.1
21+8.5
% Loss
Meyers
Process
N.D.
81+J
N.D.
N.D.
N.D.
48+3
Gain
11+5
-
25+9
56+14
N.D.
N.D.
N.O.
75+_30
N.D.
N.D.
70+5
f loot-Sink
>50
81+_1
N.D.
21+_4
N.D.
48+3
38+5
36+6
-
50+9
33+_13
29+20
N.D.
N.D.
-
N.D.
N.D.'
42+_13
10
10

-------
                                                    Table F-9

                                           TRACE ELEMENT ANALYSIS (PPM)


                        BIRD NO. 3 MINE, LOWER KITTANNING SEAM, SOMERSET COUNTY, PENNSYLVANIA
Element
Ag
As
6
Be
Cd
Cr
Cu
F
Hg
Li
Mn
Hi
Pb
Sb
Se
Sn
V
Zn
Individual Values
Raw Coal
1.5 4.3
17.5 14.8
29.8 29.9
3.5 3.6
1.5 1.4
152 146
23 29
115 95
o.in n.in
63 45
46 44
35 36
26 20
16+1.9
14.8+0.10
1.0+.07
0.5+0.29
88+5.9
15+4.4
+10+15.2
-
9+13.4
36+1.8
2+14.8
+21+15.4
Ind
_
+5+15.0
+5+21.0
71+14.2
Float-Sink
1.9+1.98
12+1.9
27+. 21
+0.4+_.07
+0.1+_.70
93+4.2
10+4.3
57+14.1
-
38+12,7
25+2.5
+8+J4.9
1+6.5
>+39+8
_ _
+26+24
26+19.8
56+14.1
% Loss
Meyers
Process
N.D.
98+1
50+0.3
28+1
36+20
59+3
58+9
N.D.
-
N.D.
80+3
N.D.
Gain
Ind
_
N.D.
N.D.
89+3
Float-Sink
66+24
75+3
92+1
Gain
N.D.
62+J
38+10
54+6
-
70+7
56+5
N.D.
N.D.
Gain
_
N.D.
43+T9
70+5
ro
o
o

-------
                                                       Table F-10

                                              TRACE  ELEMENT ANALYSIS (PPM)


                                    MEIGS  MINE,  CLARION 4A SEAM,  MEIGS COUNTY,  OHIO
Element
Ag
As
b
Be
Cd
Cr
Cu
F
Hg
Li
Mn
Ni
Pb
Sb
Se
Sn
V
Zn
Individual Values
Raw Coal
0.5 0.7
2.7 2.5
120 110
1.6 1J
0.8 0.7
99 100
24 22
220 224
0.04 0.06
22 23
40 49
20 23
12 13
16 <5
58 68
5 25
55 46
40 36
Treated Coal
Meyers Process
<1 <1
-
100 100
2.0 1.5
<0.5 <0.5
49 47
13 14
197 223
-
21 22
14 18
22 24
2 11
<5 <5
. <5 <5
32 23
41 42
10 8
Float-Sink
<1 <1
-
100 90
1 1
2 1
50 51
12 10
71 65
-
-
23 19
26 21
22 23
32 35
-
17 20
45 45
28 29

Raw Coal
0.6+0.14
2.6+0.14
115+7.1
1.4+0.35
0.8+.07
100+0.7
23+1.4
222+2.8
0.05+0.014
22.5+0.71
44+6.4
22+2.1
12+0.7
9+9.6
63+7.1
15+14.1
50+6.4
38+2.8
Average Values
Treated Coal
teyers Process
<1
-
100+0
1.8+0.35
<0.5
48+1.4
14+0.7
210+18.4
-
21.5+0.71
16+2.8
23+1.4
6.5+6.4
<5
<5
28+6.4
42+0.7
9+1.4
Float-Sink
<1
-
98+3.5
1+0
1.5+0.7
50+0.7
11+0.7
68+4.2
- -
11+0
21+2.8
24+3.5
22+0.7
34+2.8
- -
18+2.1
45+0
28+0.7
PPM Change
Meyers
Process
Ind
-
15+7.1
+ 0.4+.43
>0.3
52+1.6
9+1.6
12+18.6
- -
1+1.0
28+7.0
+1+2.5
5.5+6.44
N.D.
- -
+13+15.8
8+6.4
29+3.1
Float-Sink
<1
_
17+7.9
0.4+.35
+0.7+.70
50+_1.0
12+1.6
154+5.0
- -
12+_.7
23+7.0
+2+4.0
+10+1.0
+25+10
- -
+3+14.2
5+6.4
10+2.9
% Loss
Meyers
Ind
_
13+5
N.D.
>38
52+1
39+5
N.D.
-
N.D.
64+8
N.D.
N.D.
N.D.
-
N.D.
16+10
76+4
Float-Sink
Ind
_
15+6
29+J8
N.D.
50+1
52+4
69+2
-
51.+2
52+9
N.D.
Gain
Gain
-
N.D.
N.D.
26+6
ro
o

-------
                                                      Table F-ll

                                             TRACE ELEMENT ANALYSIS (PPM)


                                  KEN MINE, NO. 9 SEAM, OHIO COUNTY, (WEST) KENTUCKY
Element
Ag
As
B
Be
Cd
Cr
Cu
F
Hg
Li
Mn
Ni
Pb
Sb
Se
Sn
V
Zn .
Individual Values
Raw Coal
1.7 1.2
6.5 6.5
60 60
2.0 2.0
2.3 1.1
75 78
17 16
126 123
<0.2 <0.2
9 9
64 56
35 26
19 13
30 17
<5 <5
<5 21
32 38
40 39
Treated Coal
Meyers Process
1 2
0.5 0.5
60 60
3 3
1 <.5
37 35
12 12
87
-
10 10
5 5
16 17
4 4
29 40
_
4 4
22 19
19 15
Float-Sink
<1 <1
1 1
55 50
1 1
2 3
40 40
9 8
59 49
-
5 6
33 34
27 25
23 19
12 8
-
43 25
31 26
35 36

Raw Coal
1.4+0.35
6.5+0
60+0
2.0+0
1.7+0.8
76+2.1
16+0.71
124+2.1
<0.2
9+0
60+5.7
30+6.4
16+4.2
24+9.2
1+1.4
12+13.1
35+4.2
40+0.7
Average Values
Treated Coal
teyers Process
1.5+0.71
0.5+0
52+3.5
3+0
2.5+0.71
36+1.4
8+0.7
54+7.1
- -
10+0
5+0
16+0.71
4+0
34+7.8
- -
4+0
20+2.1
17+2.8
Float-Sink
<1
1+0
52+3.5
1+0
2+0.7
40+0
8+0.7
87
- -
6+0.7
34+0.7
26+1.4
21+2.8
10+3.5
- -
34+12.7
28+3.5
36+0.7
PPM Change
Meyers
Process
+0.1+0.79
6+0
8+3.5
+1+0
+0.8+1.1
40+2.5
8+1.4
70+7.4
- -
+1+0
55+5.7
14+6.4
12+4.2
+10+12
- -
8+13.1
15+4.7
23+2.9
Float-Mnk
>0.4+_.35
5.5+0
8+3.5
1+0
+0.3+J.1
36+2.1
8+1.4
37+7.4
- -
3+0.7
26+5.7
4+6.6
+5+5.0
14+9.8
- -
+22+18
7+5.5
4+1.0
* Loss
Meyers
Process
N.D.
92+0
13+6
Gain
N..O.
53+2
50+5
56+6
-
N.D.
92+1
47+J2
>5+7
N.D.
-
67+36
43+9
58+7
Float-Sink
28+17
85+0
13+6
50+0
N.D.
47+2
50+5
30+6
-
33+8
43+6
N.D.
N.D.
58+22
-
Gain
20+14
10+3
r>o
o
ro

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                          REFERENCES FOR APPENDIX F


 15.  American  Public  Health Association (APHA), American Water Works
     Association,  and Water Pollution Control Federation, "Standard
     Methods for the  Examination of Water and Waste Water," 13th ed.

 16.  Horowitz, W.  ed.,  "Official Methods for Analysis of the Association
     of Official Analytical Chemists," llth ed. "(1970).

 17.  ASTM  Committees  D-19  and D-23, "Water:  Atmospheric Analysis,"
     Part  23,  D2972-71-T,  "Tentative Method of Test for Arsenic in
     Water," (1971),  859-61.

 18.  Angino, E. E. and  G.  K. Billings, "Atomic Absorption Spectrometry,"
     in Geology Methods  in Geochemistry and Geophysics. Elsevier
     Publishing Co.,  New York (1967).

 19.  Rains, T.  C.  and 0.  Menis, "Accurate Determination of Submicrogram
     Amounts of Mercury  in Standard Reference Materials by Flameless
     Atomic Absorption  Spectrometry,"  Analytical Chemistry Division,
     National  Bureau  of  Standards, Washington, D.C.

 20.  Wilson L., "The  Determination of Cadmium in Stainless Steel by
     Atomic Absorption Spectroscopy,"  Anal. Chim. Acta., 35, (1966),
     123-126'.

 21.  Delgado,  L. C. and  D. C. Manning, "Determination of Vanadium in
     Steels and Gas Oils," Atomic Absorption Newsletter, 5 (1), (1966).

 22.  Slavin, W., "Atomic Absorption Spectrometry," Interscience Publishers,
     (1968).

 23.  Ramakushna, T. V., et al, "Determination of Copper, Cadmium and  Zinc
     by Atomic Absorption Spectroscopy," Anal. Chim. Acta., 37, (1967),
     20-26.

 24.  Delgado,  L. C. and  D. C. Manning, "The Determination by Atomic
     Absorption Spectroscopy of Several Elements Including Silicon,
     Aluminum  and Titanium in Cement," Analyst, 92 (Sept. 1967),
     553-557,

25.  Hatch, R.  R.  and W. L. Ott, "Determination of Sub-Microgram
     Quantities of Mercury by Atomic Absorption Spectrophotometry,"
     Anal.  Chem. 40 (14), (Dec. 1968), 2085-2087.

26.  Perhac, R. M.  and C. J. Whelan, "A Comparison of Water-Suspended
     Solid and Bottom Sediment Analysis for Geochemical Prospecting
     in a Northeast Tennessee Zinc District," Journal of Geochemical
     Exploration.  1. 47-53, (1973).

27   US  Bureau of Mines, Report No.  7184, " Colon'metric Method for
     Arsenic in Coal," No. 7184, (1968).

                                   203

-------
                       REFERENCES  FOR APPENDIX  F  (continued)


28.  Fisher Technical  Paper TD  142, "Reagent  of Choice for Arsenic,"
     TD 142, (1960).

29.  Peterson,  H.  P.  and D. W.  Faranski,-Anal.  Chem. 44(7),  1291,  (1972).

30.  Mair,  J. W.,  Jr.  and H.  G.  Day, "Curcumin  Method for Spectrophotometric
     Determination of  Boron Extracted from  Radio-Frequency Ash Animal
     Tissues Using 2-Ethyl-l,3-Hexanediol," Anal. Chem. 44 (12) 2015-2017,
     (Oct.  1972).

31.  McFarren,  E.  F. ,  et al,  Water Fluoride No. 3, Study No. 33, "Report
     of a Study Conducted by  Analytical  Reference Service for the  U.S.
     Department of Health, Education, and Welfare,"  PB 215-504, (1969).

32.  Kneip, J.  J., et  al, "Tentative Method of  Analysis for  Chromium
     Content of Atmosp.  Part. Matter by  Atomic  Absorption Spectres copy,"
     Health Lab. Sci. . 10 (4),  357-361, (Oct.  1973).

33.  Lishka, R.  J. and E. F.  McFarren, Water  Trace Elements  No. 2,  Study
     No.  26. "Report  of a Study Conducted  by the Analytical Reference
     Service for the  U.S. Department of  Health, Education and Welfare,"
     PB 218-501  (1966).

34.  Peters, E.  T., J. E. Oberholtzer and J.  R. Valentine,  "Development
     of Methods for Sampling  and Analysis of  Particulate  and Gaseous
     Fluorides  from Stationary  Sources,"  Prepared for EPA by Arthur D.
     Little under  Contract 68-02-0099,  PB 213-313,  (November 1972).

35.  "Instrumental Analysis of  Chemical  Pollutants," Training Manual
     Published  by  Environmental  Protection  Agency Water Quality Office,
     April  1971, PB 214-504.

36.  "Determination of Hazardous Elements in  Smelter-Produced Sulfuric
     Acid," Prepared  for EPA by Monsanto Research Corp.  under  Contract
     68-02-0226, EPA  650.2-74-131, (Dec. 1974).

37.  Tucker, G.  H. and H. E.  Malone, ^Atmospheric Diffusion  of  Beryllium,"
     Final  Report  A/F Sys. Command AFRLP-TR-70-65,  Vol.  No.  1,  113,
     (July  1971).

38.  Baldeck, C. and  G.  W. Kalb, "The  Determination  of  Mercury  in  Stack
     Gases  of High S02 Content  by the  Gold  Amalgamation  Technique,"
     Prepared for  EPA by TraDet, Inc.,  under Contract  68-02-0697,
     PB 220-323.
                                   204

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                                TECHNICAL REPORT DATA
                          (Hcne n* ImUiBCliau am IlK irvent ttfon t
 . REPORT NO.
 EPA-650/2-74-025-a
                                                      I. RECIPIENTS ACCISSIOKNO.
4. TITLE AND SUBTITLE
Applicability of the Meyers Process for Chemical
   Desulfurization of Coal: Survey of 35 Coals
                                  I. REPORT DATE
                                  September 1975
                                  I. PERFORMING ORGANIZATION CODE
7. AUTHOR(S)

J.W. Hamersma and M. L. Kraft
                                  1 PERFORMING ORGANIZATION REPORT NO.

                                      22234-6023-RU-00
 I. PERFORMING ORGANIZATION NAME AND ADOREM~
 Systems Group of TRW, me.
 One Space Park
 Redondo Beach, CA  90278
                                  10. PROGRAM ELEMENT NO.	

                                      13: ROAP 21ADD-096
                                 |11. CONTRAcT/flRANT NO.

                                  J8-02-0647
 12. SPONSORING AGENCY NAME AND AOORESS
 EPA, Office of Research and Development
 Industrial Environmental Research Laboratory
 Research Triangle Park, NC 27711
                                 IIX TYPE OF REPORT AND PERIOD COVERED
                                  final
                                  14. SPONSORING AGENCY CODE
18. SUPPLEMENTARY NOTES
is. ABSTRACT The report details experimentation on the application of chemical cleaning
(desulfurizatton) technology to a variety of U.S.  coals. Run-of-mine coal samples
were collected from 35 U.S. coal mines in 13 states.  Each sample was treated
separately by the Meyers process for selective chemical removal of coal-pyrite and
by float-sink procedures for physical coal cleaning. Raw and chemically treated coals
were examined for sulfur distribution as well as for selective trace element distri-
bution and other process characterizing features, such as heat content and ash
changes and leaching agent residuals. Comparisons of physical and chemical impacts
on sulfur reductions are discussed.
 7.
                             KEY WORM AND DOCUMENT ANALYSIS
                DESCRIPTORS
                                          k. IDENTIFIERS/OPEN ENDED TEM
                                                                   f. COSATI
Air Pollution
Coal
Coal Preparation
Desulfurization
Sulfur
Pyrite
Trace Elements
Air Pollution Control
Stationary Sources
Meyers Process
Chemical Cleaning
Ferric Sulfate Extraction
Float-Sink Fractionation
13B
8G, 21D
81
7A
7B
'*. DISTRIBUTION STATEMENT

Unlimited


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                                         205

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