EPA-650/2-74-127
DECEMBER 1974
Environmental Protection Technology Series
-------
EPA-650/2-74-127
EVALUATION OF SULFUR DIOXIDE
EMISSION CONTROL OPTIONS
FOR IOWA POWER BOILERS
by
D. O Moore, Jr. , J M Pctert.
W S. Alper, E. Rosen, and J . R Burke
The M W. Kellogg Company
1300 Three Greenway Plaza East
Houston, Texas 77046
Contract No. 68-02-1308, Task 3
ROAP No. 21ADD-079
Program Element No. 1AB013
EPA Project Officer: James D. Kilgroe
Control Systems Laboratory
National Environmental Research Center
Research Triangle Park, North Carolina 27711
Prepared for
OFFICE OF RESEARCH AND DEVELOPMENT
U.S. ENVIRONMENTAL PROTECTION AGENCY
WASHINGTON, D.C. 20460
December 1974
-------
This report has been reviewed by the Environmental Protection Agency
and approved for publication. Approval does not signify that the
contents necessarily reflect the views and policies of tho Agency,
nor docs mentioir of trade names or commercial products constitute
endorsement or recommendation for use.
11
-------
TABLE OP CONTENTS
Page No,
I. Introduction 1
II. Summary and Conclusions 6
III. Overall System Evaluation 30
A. Basic Assumptions Made for the System 31
to Use in the Linear Computer Program
B. Linear Computer Program Results 33
IV. Process Descriptions 44
A. Flue Gas Scrubbing Processes 44
1. Wet Limestone System
2. Wellman-Lord System
3. Allied System
B. Coal Cleaning Process 58
V. Descriptions of Power Plants in Iowa 62
VI. Estimates for Flue Gas Scrubbing ««
A. Detailed Estimates for Wet Limestone 90
Systems
B. Computerized Estimates for Both Scrubbing 94
Systems
1. Wet Limestone Cost Model
2. Wellman-Lord/Allied Cost Model
C. Comparative Economics of Wet Limestone 105
vs. Wellman-Lord/Allied
VII. Linear Programming Model 115
A. A Brief Discussion of Linear Programming 115
B. The Definition of the Problem in Terms of an LP us
Model
C. Solution Using KELPLANS 125
111
-------
Page No.
VIII. References 139
IX. Glossary 141
X. Appendices 143
A. Power Plant Input Data 144
B. Wet Limestone System 183
B-l. Process Flow Sheets
B-2. Equipment List
B-3. Standard Scrubber Modules
B-4. Standard Sizes for Venturi
Scrubbers and Absorbers
B-5. Standard Limestone System -
Plan & Elevation
B-6. Sludge Pond Size Sheet
B-7. Plot Plans for Each Plant -
Wet Limestone Systems Added
C. Wellman-Lord/Allied System 205
C-l. Process Flow Sheets
C-2. Equipment List
C-3. Standard Scurbber Module
C-4. Standard Wellman-Lord System Plan
C-5. Standard Component Sizes
C-6. Plot Plans for Each Plant -
Wellman-Lord/Allied Systems Added
D. Coal Cleaning System 225
D-l. Process Flow Sheet
D-2. Equipment List
D-3. Simplified Plot Plan - Typical
600 TPH Plant
E. Plot Plans of Other Power Plants 230
F. Conversion from English to Metric Units 237
G. Linear Computer Program Print-outs (Abridged) 239
iv
-------
LIST OF FIGURES
Figure No. Title Page No.
1 Plot of Incremental System Costs vs. S02 43
Emission Specification
2 Scrubbing System Costs vs. % Sulfur 114
3 Wet Limestone Scrubbing Costs Used in 127
Linear Program
4 Coal Cleaning Costs Used in Linear Program 128
5 Process Flow Diagram - Limestone and Effluent 184
System
6 Process Flow Diagram - Scrubber System 185
7 Standard Scrubber Module - Type A: Size I 190
8 Standard Scrubber Module - Type B: Size I 191
9 Standard Scrubber Module - Type C: Size I 192
10 Standard Limestone System - Plan and Elevation 195
11 Plot Plan - Des Moines Plant - Wet Limestone 197
Scrubbing System
12 Plot Plan - Maynard Plant - Wet Limestone 198
Scrubbing System
13 Plot Plan - Muscatine Plant - Wet Limestone 199
Scrubbing System
14 Plot Plan - Riverside Plant - Wet Limestone 200
Scrubbing System
15 Plot Plan - Burlington Plant - Wet Limestone 201
Scrubbing System
16 Plot Plan - Kapp Plant - Wet Limestone 202
Scrubbing System
17 Plot Plan - Prairie Creek Plant - Wet Limestone 203
Scrubbing System
18 Plot Plan - Sutherland Plant - Wet Limestone 204
Scrubbing System
19 Process Flow Diagram - Wellman-Lord Process 206
20 Process Flow Diagram - Allied Chemical Process 207
21 Standard Scrubber Module - Wellman-Lord Process 214
22 Standard Module Plans - Wellman-Lord/Allied 215
Process
-------
LIST OF FIGURES CON'T.
Figure No. Title
Page No.
23 Plot Plan - Des Moines Plant - Wellman- 217
Lord/Allied Process
24 Plot Plan - Maynard Plant - Wellman- 218
Lord/Allied Process
25 Plot Plan - Muscatine Plant - Wellman- 219
Lord/Allied Process
26 Plot Plan - Riverside Plant - Wellman- 220
Lord/Allied Process
27 Plot Plan - Burlington Plant - Wellman- 221
Lord/Allied Process
28 Plot Plan - Kapp Plant - Wellman-Lord/ 222
Allied Process
29 Plot Plan - Prairie Creek Plant - Wellman- 223
Lord/Allied Process
30 Plot Plan - Sutherland Plant - Wellman- 224
Lord/Allied Process
31 Process Flow Diagram - Coal Cleaning Process 226
32 Simplified Plot Plan - Coal Cleaning Plant 229
33 Plot Plan - Pella Plant 231
34 Plot Plan - Iowa State University Plant 232
35 Plot Plan - Fair Plant 233
36 Plot Plan - Dubuque Plant 234
37 Plot Plan - Lansing Plant 235
38 Plot Plan - Sixth Street Plant 236
VI
-------
LIST OF TABLES
Table No. Title Page No,
1 Case 1 - Summary of Costs 40
2 Case 2 - Summary of Costs 41
3 Case 3 - Summary of Costs 42
4 Economic Comparison of Wet Limestone vs. 109
Wellman-Lord/Allied
5 Power Plant Input Data - Des Moines Plant 145
6 Stack Gas Scrubbing System - Des Moines Plant 150
7 Power Plant Input Data - Maynard Plant 151
8 Stack Gas Scrubbing System - Maynard Plant 156
9 Power Plant Input Data - Muscatine Plant 157
10 Stack Gas Scrubbing System - Muscatine Plant 160
11 Power Plant Input Data - Riverside Plant 161
12 Stack Gas Scrubbing System - Riverside Plant 166
13 Power Plant Input Data - Burlington Plant 167
14 Stack Gas Scrubbing System - Burlington Plant 170
15 Power Plant Input Data - Kapp Plant 171
16 Stack Gas Scrubbing System - Kapp Plant 174
17 Power Plant Input Data - Prairie Creek Plant 175
18 Stack Gas Scrubbing System - Prairie Creek Plant 173
19 Power Plant Input Data - Sutherland Plant 179
20 Stack Gas Scrubbing System - Sutherland Plant 182
21 Equipment List - Wet Limestone System 186
22 Absorber-Venturi Standard Sizes 193
23 Wet Limestone Process - Scrubber Area Dimensions 194
24 Sludge Pond Size Sheet 196
25 Equipment List - Wellman-Lord/Allied Process 208
26 Wellman-Lord/Allied Process Standard Sizes 216
27 Equipment List - Coal Cleaning Plant 227
VII
-------
ACKNOWLEDGMENTS
The authors wish to gratefully acknowledge the assistance and
support of a number of persons and groups who provided valuable
contributions to this project. The U.S. Environmental Pro-
tection Agency, the Iowa Geological Survey, and the Iowa Depart-
ment of Environmental Quality provided aid in defining the
nature and scope of the task. Gates Engineering Company of
Beckley, West Virginia performed the study entitled "Feasibility
Study of Iowa Coals" which gave essential background information
for the study. The Iowa electric utility industry provided
data and drawings for the power plants which were used ex-
tensively in the preparation of the report.
vni
-------
I. INTRODUCTION
This report presents the results of a detailed study performed
for the U. S. Environmental Protection Agency (Contract 68-02-
1308, Task No. 3) and administered by the Iowa Geological Survey
and the EPA. Close liaison and cooperation with the Iowa Depart-
ment of Environmental Quality (IDEQ) and with the electric utility
industry in Iowa were also essential aspects of this task..
The primary objective of this task was to study coal burning
power plants in Iowa as a system and to evaluate various emission
control strategies for this system which would minimize total
operating costs while meeting selected S02 emission levels. To
accomplish the objective it was necessary to determine the feas-
ibility of building centralized facilities for physical cleaning
of indigenous and "foreign" coals used in Iowa's coal-fired
steam-electric generating plants. It was also necessary to
determine the feasibility of stack gas scrubbing at some of the
more problematic plants, as selected by the IDEQ. The impetus
for the study was a need to determine optimal (minimum) costs
of reducing power plant emissions of sulfur dioxide to or below
regulation levels. In recent years increasingly more costly
materials and,services and scarcer clean fuels have made it
difficult to economically meet stringent environmental constraints.
There are currently 35 power plants in the state which were de-
signed to burn coal in at least one boiler per plant. Although
many of them also consumed natural gas and fuel oil in past
years, the assumption was made for this study that the Btu require-
ment in each plant capable of firing coal, was met exclusively
with coal. The total generating capacity in the state is present-
ly some 3093 mw (excluding that produced by two plants not de-
signed for coal). Most of the plants are small, often with dimin-
utive boilers which were added piecemeal over the years as power
demands grew; rated capacities of the power plants range from
4.6 to 490.8 mw.
-------
The plants selected for the stack-gas study are as
follows:
Des Moines Power Station No. 2, Des Moines
Pella Plant, Pella
Iowa State University Plant, Ames
Maynard Plant, Waterloo
Muscatine Plant, Muscatine
Fair Plant, Montpelier
Riverside Plant, Bettendorf
Burlington Plant, Burlington
Dubuque Plant, Dubuque
Lansing Plant, Lansing
Kapp Plant, Clinton
Prairie Creek Station, Cedar Rapids
Sixth Street Station, Cedar Rapids
Sutherland Plant, Marshalltown
To obtain data and drawings and to permit comprehensive
evaluation of each plant, the following actions were taken:
(1) an introductory letter was sent by the Iowa Geological
Survey to each of the utility home offices, explaining the
purpose and conduct of the study; (2) questionnaires
were mailed to the utilities) with more detailed informa-
tion requested from the above listed plants; (3) Federal
Power Commission Forms (FPC 67), detailing the plants'
fuel consumption, operating parameters and effluent charater-
istics, were obtained from the EPA; and (4) visits were
made to each of the plants above.* Additionally, photographs
were taken at some of the sites when weather permitted.
* The Lansing plant was not visited due to time limitations;
however, adequate data and drawings were provided by the
Interstate Power Company and the EPA.
-------
The EPA Task Order specified that two flue-gas scrubbing methods
be considered: the wet limestone system and a regenerable
sorbent system which yields by-product elemental sulfur. Be-
cause the WeiIman-Lord/Allied process has been applied at plant
scale, it was selected for the second system. Some operating
data are available for both methods; however, no attempt is
made in this report to evaluate whether or not flue-gas scrubbing
is proven technology. Instead the basic approach included
application of available operating and design data to the power
plants selected for consideration of equipment retrofit.
To accommodate a range of boiler sizes, a graduated set of stan-
dard scrubber modules was developed for both processes. Eight
standard modules.were designed from which an appropriate size
and number could be selected for each application. For the wet
limestone ststem, storage, preparation and handling equipment
were sized and cost estimates were prepared for each plant.
Major use was made of computerized cost models in estimating
capital and operating costs for both systems. Additionally,
detailed estimates of capital costs of wet limestone systems
were made by Kellogg1s Estimating Department. Because of the
nature of the estimates, the accuracy of vendor quotes, the lack
of a completely definitive design, and other factors, the overall
accuracy of the estimates is probably 30-35%, with the probability
of underrun being very small.
Physical cleaning of coal was examined in this study as a
possible alternative to flue-gas scrubbing. A subcontract was
let to Gates Engineering, Inc., Beckley, West Virginia, to
determine the availability, locations, costs, characteristics
and washabilities of coals in Iowa, Illinois and Kentucky; the
same parameters (except washability) were provided for Colorado,
Wyoming and Montana coals. Also, capital and operating cost data
-------
were estimated for a typical 600 t/h Cfeed) coal-cleaning faci-
lity, and several likely locations were suggested for several
centralized plants of like size.
Because of the large number of variables involved in determin-
ing the lowest system cost for reducing sulfur emissions in the
state, it was necessary to devise a linear programming (LP) model
capable of accommodating the many possible permutations and
optimizing (minimizing) the system costs. Among these variables
were transportation modes and costs, coal characteristics, coal
costs and mine locations, power plant locations and fuel demands,
possible cleaning plant locations and costs, and scrubbing
equipment costs and characteristics. Much information compris-
ing the data base was obtained from the coal-cleaning subcontract
and was then used as input to solve the LP model. Using a matrix-
generation routine and an optimization routine, the LP model is
solved by computer to determine the optimal systen costs for
sulfur reduction.
The linear programming model, developed by Kellogg's Information
Systems Department, proved to be a very useful tool. Once the
model was perfected it was readily modified to accommodate a
range of sulfur emission specifications, mine capacities, coal
costs, transportation costs and other parametric constraints.
Of course only one variable was allowed to change at a time so
that the optimal solutions could be properly correlated. The
resulting set of minimal system costs provided important inputs
to the conclusions given in the next section.
The proposed sulfur dioxide emission regulation for the State
of Iowa (on power plants not subject to Federal New-Source
regulations is 6.0 pounds of S02 per million Btu of heat input
(based on higher heating value of fuel) for coal-fired boilers.
The present emission standard set by the Iowa Air Quality Commission
(effective January 1, 1975) is 5 Ib S02/MM Btu. It is worthy to
note that this regulation is- one of the least stringent con-
straints in the United States. Since it is oossible that other
S02 emission controls will be imposed, it was decided to use a
4
-------
range of sulfur control specifications for the linear program
work. Thus we have been able to present comparative costs for
optimal sulfur control at various specification levels. Sulfur
dioxide emission levels used in his study included no control,
5.0, 3.1, and 1.2 Ib S02/MM Btu.
A total of 18 power plants (2737 mw) were used in the linear
computer program. At 100% generating capacity, these plants
require about 35,000 t/d of coal. The use of a load factor of
about 65-70% for these plants would more nearly approximate the
actual Iowa coal demand. However, the conclusions reached
regarding incremental system costs (in C/MM Btu) to meet any
given specification would not change.
All costs used in the study - scrubbing system capital and
operating costs, coal cleaning costs, coal pithead costs, ash
and refuse disposal costs, coal storage/transfer cost, and rail
and barge freight rates - are on a January, 1974 basis. The
conclusions of the study are based on the assumptions made.
The present unprecedented inflation rate leads to rapidly
changing equipment, coal, and transportation costs. Therefore
certain limitations exist when attempting to predict the ootimal
sulfur dioxide control strategy a few years hence.
Since this study was conducted for the State of Iowa, it follows
that the conclusions apply only to that state due to Iowa's
particular geographic location and power plant network.
It is recognized that the needs of other states for low sulfur
western coal will make competition for this fuel very keen. How-
ever, the assumption was made for this study that at least 16,000 tpd
will be available to Iowa utilities.
-------
II. SUMMARY AND CONCLUSIONS
A. General Conclusions Pertaining to Coal as an Energy Source
There is no question that coal is the most abundant fossil fuel
energy source in the United States. Coal accounts for 87.1* of
the mineral fuel reserves in the country. Oil and gas account
for 8.1? and shale and others account for 4.8* (1, p. 29). The
total coal reserves in the United States are estimated to be
some 3,210 billion tons (1, p. 432) or 48.1* of the estimated
total world reserves (1, p. 32). There is far more coal in
this country than in any other country in the world.
Of the total coal reserves in this country, about 71-3* is predicted
to be bituminous, sub-bituminous, and anthracite (1, p. 432).
If half of this coal can be considered recoverable, the usable
reserves are approximately 1,144 billion tons (assuming no land
use restrictions). In 1972, the steam-electric utility plants
in the U.S. consumed fuel (coal, oil, and gas) at the rate
equivalent to 634.9 MM tons of coal per year. At that rate of
consumption, there is enough coal to last about 1,800 years. If
the steam-electric utilities are allocated only 60% of the coal
reserves (and assuming they burn coal exclusively), the reserves
will last about 1,080 years. Finally, assuming a continued
increase in the electric power demand, it is easy to see that
there is enough coal to last for hundreds of years.
The reserves of coal in the U.S. containing 1* sulfur or less are
estimated to be about 65% of the total tonnage (based on a study
done in 1966 by the Bureau of Mines - 1, p. 203). About 6% of
the total reserves (containing 1* sulfur or less) lie in the eight
major coal producing states (Alabama, Illinois, Indiana, Kentucky,
Ohio, Pennsylvania, Virginia, and West Virginia). About 59%
of the total reserves (containing 1% sulfur or less) are estimated
to be in states which are not now major coal producers (principally,
Colorado, Montana, New Mexico, North Dakota, and Wyoming). Hence
it may be concluded that while there are abundant reserves of low
-------
sulfur coal in the country, drastic changes will be needed in the
coal industry as well as in transportation to enable the steam-
electric utility industry to use this coal.
B. General Conclusions Regarding the Supply of Coal for the State of Iowa
The steam-electric power generating capacity in the State of Iowa
(in 1972) is 3093 mw (9, p. 17). This power is generated at 35
plants having the ability to burn coal (some also can burn oil
or gas). Two plants which burn only oil and gas and have a
generating capacity of 19 mw total were not considered. The
generating capacity in Iowa is fairly low - about 1% of the total
in the United States (9, p. 53). The average load factor for all
steam-electric power plants in Iowa in 1972 was 51% (9, p. 17).
If the average load factor is assumed to increase to 60% in 1974
due to population and industrial growth as well as increased use
of electrical equipment, and if the total energy requirement is
met with coal, then the total coal requirement for the state will
be about 8.66 MM tons/year (about 23 ,700 tons/day on a 365 day
basis). Assumed are a heat rate of 12,000 Btu/kwh and an HHV of
11,260 Btu/lb.
Total coal reserves in the State of Iowa are estimated to be
7,236 MM tons in seams thicker than 14 inches (2, p. 4). These
reserves are located in 25 seams and are broken down as follows:
Thickness MM Tons
14" - 28"
28" - 42"
+ 42"
Total
The tabulation shows that 5,076 MM tons exist in seams 28" or
more in thickness which could be mined economically. Another
source (1, p. 432) credits Iowa with known bituminous coal reserves
-------
of 6,519 MM tons with another 14,000 MM tons being estimated to
exist in unmapped and unexplored areas. No matter which estimate is
used, it is evident that there is enough coal in Iowa to meet the
demand of the steam-electric utility industry for hundreds of years.
However, the quality of Iowa coal is rather poor. The sulfur
content ranges from 4-8%, the ash content from 12-23%, and the
higher heating value (HHV) from 9,400-11,500 Btu/lb (2, p. 6).
Therefore, owing to air pollution regulations, Iowa coal cannot
be used unless one or more of the following control measures is
put into effect:
- low sulfur coal blending
- coal cleaning
- stack gas scrubbing
The logical states to choose as alternative suppliers of coal for
Iowa are Illinois, Kentucky, Wyoming, Colorado, and Montana (as
well as possibly Kansas and Oklahoma). Illinois has the largest
known bituminous coal reserves in the United States and Kentucky
has the third largest. However, these coals have intermediate
sulfur contents (about 2-4% sulfur) and cannot be used exclusively
to meet stringent air pollution regulations (2, p. 8). Wyoming,
Colorado, and Montana are the best potential suppliers of low
sulfur coal (<.!%) for the State of Iowa. The following table gives
the breakdown of coal reserves of the states considered as suppliers
(1, p. 432) :
Coal Reserves of Potential Supply States (MM tons)
Overburden 0 - 3000 Ft. Thick
Resources Determined by Mapping and Exploration
Bituminous Sub-bituminous
Coal Coal Lignite Anthracite Total
Colorado
Illinois
Iowa
Kentucky
Montana
Wyoming
62,389
139,756
6,519
65,952
2,299
12,699
18,248
0
0
0
131,877
108,011
0
0
0
0
87,525
0
78
0
0
0
0
0
80,715
139,756
6,519
65,952
221,701
120,710
-------
C. General Conclusions Reached When Comparing the Use of Low Sulfur
Coal to Stack Gas Scrubbing to Meet an Emission Specification of
1.2 Ib S02/MM Btu
When low sulfur coals are located reasonably near the demand sites
and when low cost unit train rates may be applied, the use of low
sulfur coal appears to be superior to the use of stack gas scrubbing
to meet emission regulations (particularly when the power plants
are small, e.g., <250 mw, and difficult to retrofit with scrubbing
facilities). This is the case in the State of Iowa where western
coal is about 1000 miles away and the power plants are small.
Simplified incremental system costs are shown below assuming equal
coal pithead cost, Btu value, ash content, etc.
Basis: 250 MW Plant
Coal HHV = 10,000 Btu/lb
Incremental distance = 1000 miles
Use of Low Sulfur Coal Stack Gas Scrubbing
1000 Mi ($0.005/T Mi) (100) = 25C/MM Btu 40-45C/MM Btu
20 MM Btu/ton
If transportation costs increase 60-80% (to $0.008-0.009/T-Mi)
or if low sulfur western coals cost 15-20C/MM Btu more than local
coals, then the two cases would be essentially equal.
When low sulfur coals are located at great distances (> 1500
miles) from the demand sites and when the power plants are large
(> 500 mw) and relatively easy to retrofit with stack gas
scrubbing facilities, the use of stack gas scrubbing appears
to be superior. This is not the case in Iowa.
Basis: 1000 MW Plant
Coal HHV = 10,000 Btu/lb
Incremental Distance = 1500 miles
-------
Use of Low Sulfur Coal Stack Gas Scnibbing
1500 Mi ($0.005/T-Mi) (100) = 37.5CMM Btu 30-35C/MM Btu
20 MM Btu/ton
If it should be determined that the use of either control measure
(low sulfur fuel or stack gas scrubbing) would yield about the
same incremental cost in C/MM Btu, then it probably would be
advantageous to use stack gas scrubbing due to inflationary factors.
About 40-50% of the costs associated with stack gas scrubbing
will remain constant while incremental transportation costs (as
well as pithead costs) for western coals will probably continue
to rise.
The needs of other states for low sulfur coal along with finite
mining, storage, loading, and shipping facilities will likely make
competition for this source of "clean" fuel very keen. It is
likely, in turn, that delivered costs of western coals will
continue to increase.
D. Specific Conclusions Pertaining to the State of Iowa as Determined
by the Linear Computer Program.
Three cases were considered for Iowa using the linear computer
program.
Case 1: No limits are placed on any of the coal supplies.
Case 2: A limit of 16,000 t/d of western coal is imposed on the
system. This is approximately the quantity of low
sulfur coal required by the power plants for which it is
not practical to use stack gas scrubbing in order to
meet an emission specification of 1.2 Ib SC^/MM Btu.
The other eight plants are then forced by the system
constraints to use stack gas scrubbing to meet the
most stringent regulation.
10
-------
Case 3: Limits of 16,000 t/d of western coal and 7,000 t/d of
Illinois coal are imposed on the system. These limits
force the use of considerable quantities of Iowa coals
(about 40% of the total state requirement).
Four different emission levels were considered for each case
using the program.
20 Ib S02/MM Btu: This represents no control.
5 Ib S02/MM Btu: This will be the emission control level in
Iowa as of January 1. 1975.
3.1 Ib S02/MM Btu: This level was arbitrarily chosen as being
halfway between the actual emission level
and the most stringent level.
1.2 Ib S02/MM Btu: This is the Federal emission control level
for new coal-fired boilers.
For this study, the simplifying assumption was made that low
sulfur western coals could be burned in existing Iowa boilers
without modifying these boilers. In reality, it may or may not
be necessary to modify the boilers and particulate emission
control equipment depending on the properties of the particular
western coal burned and on the design of the boilers. The
modifications required, if any, may range from slight to extensive.
It was not possible to quantify the effect of burning western coals
in the existing power plants for this study. These boiler modifi-
cation costs, if accounted for, would tend to shift the optimal
cost solution in favor of stack gas scrubbing. Refer to Section
II (Part G) for a discussion of the properties of western coals
as they relate to use in existing boilers.
1. Case 1 - Unlimited western coal, unlimited Illinois coal
The following table presents the incremental system costs for
11
-------
meeting various S02 emission specifications as well as the
source of the coal for meeting the different specifications:
Incr. System Coal Used; % of Tonnage
Spec; Ib S02/MM Btu Cost; <=/MM Btu* Iowa Illinois Western Total
20 (No Control) 0.00 49.5 31.1 19.4 100.0
5 5.04 10.0 56.9 33.1 100.0
3.1 8.38 5.6 28.2 66.2 100.0
1.2 12.10 1.5 4.6 93.9 100.0
As shown by the table, the incremental system costs rise about lin-
early as the regulations become more stringent. However the increase
in cost is rather nominal (12.IOC/MM Btu), even when meeting the
most stringent regulation (1.2 Ib S02/MM Btu).
In no instances are scrubbing facilities or coal cleaning plants
installed. Instead, the more stringent regulations are met by
blending in greater quantities of western coal.
As shown in the table, whenever any emission regulation is im-
posed, the amount of Iowa coal used is rather small (dropping
from 10% of the total at a 5 Ib specification to 1.5% of the
total at a 1.2 Ib specification).
The quantity of western coal used at the 1.2 Ib specification
is fairly large - about 3 unit trains/day (note that a unit
train carries about 10,000 tons).
Western coal would need to increase in cost by about $6.50/ton
in order to obtain equal costs for Cases 1 and 2 at the 1.2 Ib
specification. It would need to increase in cost by about $7.60/ton
to obtain equal costs for Cases 1 and 3 at this specification.
These increases in cost may result from increased coal pithead
cost, increased transportation cost, or a combination of the two.
Includes all incremental coal, transportation, treatmentr storage
and disposal costs to meet the specified emission level.
12
-------
2. Case 2-16,000 T/D limit on western coal, unlimited Illinois coal
* The following table summarizes this case:
Incr. System Coal Used; % of Tonnage
Spec; Ib S02/MM Btu Cost; C/MM Btu Iowa Illinois Western
20 (No Control) 0.00 49.5 31.1 19.4
5 5.04 10.0 56.9 33.1
3.1 9.66 20.6 35.5 43.9
1.2 26.21 11.9 42.5 45.6 100.0
This case is identical to the previous case (Case 1) with no
control or with a 5.0 Ib specification. The incremental costs
are somewhat higher at the 3.1 Ib specification (about 1.3C/MM Btu)
because the limitation of western coal forces a cleaning plant
to be installed (capacity = 7,489 t/d; location - Leon, Iowa).
At the 1.2 Ib specification, a drastic increase in incremental
system cost occurs. With this regulation, scrubbing facilities
are installed at the eight plants which were considered possible
candidates for scrubbing. (Note that 16,000 t/d of western coal
is that quantity which is required in order for the other ten
plants to meet the 1.2 Ib specification). No coal cleaning
plants are installed. The incremental system cost is 26.21C/MM Btu
over no control or about 14C/MM Btu over Case 1 which has
unlimited western coal.
3. Case 3 - 16,000 T/D limit on western coal
7,000 T/D limit on Illinois coal
The following table summarizes this case:
Incr. System
Coal Used:
Spec: Ib S00/MM Btu Cost: C/MM Btu Iowa
20 (No Control) 1.03
5
3.1
1.2
8.02
12.24
28.58
59.9
38.6
40.4
38.7
Illinois
18.7
18.7
18.1
18.7
% of Tonnage
Western
21.4
42.7
41.5
42.6
Total
100.0
100.0
100.0
100.0
13
-------
In this case the Illinois coal was limited to about 20% of the
total in order to observe how the use of increased quantities
of Iowa coals influenced system costs. Under the three
control conditions (specifications of 5, 3.1 and 1.2), the total
Iowa coal used was about 14,000-15,000 t/d or about 40% of the
total. Based on the assumptions made, the incremental system
costs for this case (Case 3) rose by about 2.5-3C/MM Btu over
the costs for Case 2. The pithead costs for the Iowa coals
would have to be lowered by about $1.50/ton in order to obtain
costs equal to Case 2. Also, the costs for no control increased
by 1.034/MM Btu over Cases 1 and 2 because of the increased use
of Iowa coal.
Cleaning plants are installed under all three control conditions
due to the high sulfur content of the Iowa coals.
Spec; Ib SO^/MM Btu Cleaning Plant Size; T/D Location
5 7,200 MB*(Mine at
3.1 14,398 MB Leon
1.2 7,200 MB Iowa)
Stack gas scrubbing is installed on the eight plants (previously
deemed possible candidates) only for the most stringent regula-
tion (1.2 Ib S02/MM Btu). Note again that the use of stack
gas scrubbing causes a rather sharp increase in incremental
system costs.
E. Conclusions Regarding Coal Cleaning
e Coal cleaning (by heavy media washing) is a viable method of sulfur
removal for coals which have a relatively high pyritic sulfur
(FeS2) content. About 1/3 to 1/2 of the sulfur originally
present can be removed. No organic sulfur can be removed by this
process. A sizable reduction in ash content (about 50%) also is
* Refer to Section VII for explanation of location codes.
14
-------
realized by this process. However, about 12-16% of the Btu content
of the coal is lost (at 80% total coal recovery).
The following table lists properties of raw and cleaned coals
(80% coal recovery):
Mine
Location
Raw Coal Properties (As Received)
% Moisture % Ash % Sulfur Btu/lb
MA
MB
MC
MD
ME
Frederick, Iowa
Leon,
Ogden ,
Marion
Iowa
Iowa
, Illinois
Madisonville,
Ky.
11
18
13
7
8
.2
.0
.4
.0
.3
14.
12.
13.
14.
14.
2
8
2
9
8
5.
4.
6.
3.
4.
9
3
9
1
1
10
9
10
11
11
,038
,676
,184
,951
,801
Mine
MA
MB
MC
MD
ME
Location
Frederick, Iowa
Leon, Iowa
Ogden, Iowa
Marion, Illinois
Madisonville, Ky.
Clean Coal Properties
% Moisture % Ash % Sulfur
11.2
18.0
13.4
9.0
8.3
7.9
7.0
7.5
7.0
7.2
3.5
1.9
4.5
2.0
2.7
% HHV
Btu/lb Recovery
11,033 87.9
10,650 88.1
11,166 87.7
12,505 83.7
12,340 83.6
An examination of the table indicates that only a modest reduction
in sulfur content normally can be achieved utilizing coal cleaning.
Therefore, this process appears to be promising only when an inter-
mediate SO- emission regulation is in effect (i. e., 3.1 to 5.0 Ib
SO2/MM Btu). Obviously, cleaning of these coals will not prove to
be adequate to meet the most stringent regulation (1.2 Ib S02/MM Btu).
In some cases, a combination of coal cleaning and the use of low
sulfur coal will prove to be the logical choice to meet a given
specification.
An 80% coal recovery level was chosen for all coals after cleaning
15
-------
as this is approximately the optimum. An examination of the graph
(2, p. 16) of sulfur content vs. percent recovery for Iowa coals
reveals that the largest drop in sulfur content occurs from 100 to
80% recovery. There is very little decrease in sulfur content
as recovery drops from 80 to 60%.
The operating cost of coal cleaning (for plants in the size
range of 600 t/h raw coal feed) is about $1.90/ton feed coal. The
capital investment cost for a 600 t/h plant (which
operates 2 shifts/day for 220-260 days per year) is broken down
as follows (2, p. 13).
Capital Investment; $
Raw coal unloading and storage 1,471,000
Preparation plant 3,841,000
Clean coal handling 1,437,000
Site preparation, roads, etc. 590,000
Refuse handling 360,000
Total 7,699,000
This is equivalent to a unit investment of about $12,800/t/h for
plants in the 600 t/h size range.
Refuse disposal from a cleaning plant is expected to add about
$0.31/ton of refuse to the operating cost (2, p. 21). The operat-
ing cost for intermediate storage of coal (whether at a cleaning
plant or at a transfer point) is expected to be about $0.30/ton
of raw coal (2, p. 21).
Refuse from a cleaning plant may be disposed of by several
alternative methods. The means of transporting the refuse from
the plant is dependent on factors such as terrain, availability
of disposal areas, and quantity of material to be disposed of.
The most common methods used to transport the refuse are
trucking, belt conveyors, and aerial tramways.
16
-------
At the disposal site, earthmoving equipment must be available
to move and compact the refuse. Depending on state require-
ments, when filling of an area is completed, it may be necessary
to cover the refuse with a layer of soil and plant the area
with vegetation.
During storage of refuse, drainage facilities must be provided to
divert runoff water from adjacent areas away from the refuse
storage. Also, drainage ditches must be installed to collect
runoff water from the refuse area and send it to a pond. If
this water is acidic, provisions for treatment will be needed
before the water can be discharged into streams (2, pp. 17, 18).
The following hypothetical case is a summary of the incremental
cost to a power plant to clean a relatively high sulfur coal to
a level sufficient to meet a specification of 5.0 Ib SO2/MM Btu.
Coal Storage
Coal Cleaning
Refuse Disposal
% Sulfur HHV;Btu/lb
Raw Coal 4.0 10,000
Clean Coal 2.7 10,800
% Sulfur Removal = 46
% HHV Lost = 14
SO2 Emission = 5 Ib/MM Btu
Incremental cost 2.26 x 100
to power plant = 0.86 x 20 MM = 13-1<:/MM Btu
If, instead of cleaning, a sufficient quantity of low sulfur coal
(0.9% S) which must be transported 1,000 miles, is blended with
the 4.0% coal to meet a specification of 5.0 Ib SO-/MM Btu,
17
-------
the following cost results (assuming equal coal pithead cost,
Btu value, ash content, etc.):
% Sulfur HHV Incr. Distances; Miles
High Sulfur Coal 4.0 10,000 0
Low Sulfur Coal 0.9 10,000 1,000
Weight fraction of high sulfur coal = 0.516
Weight fraction of low sulfur coal = 0.484
Unit train freight rate = $0.005/T-mile
Incremental cost = 0.484 (1000) (0.005) (100) = 12.lt/MM Btu
to power plant 20 MM
Therefore, it can be seen that the choice between coal cleaning and
blending low sulfur coals is a close one. It depends primarily
on the following factors:
- Actual incremental distance the low sulfur coal must be
transported and the freight rate
- Pithead costs of the low vs. the high sulfur coal
- Actual ash, -moisture, Btu, and sulfur contents of the
two coals
- Degree of sulfur removal attained when cleaning the high
sulfur coal
- Rate at which new low sulfur coal supplies can be made
available
18
-------
F. Conclusions Regarding Stack Gas Scrubbing
1. Capital Investment
The following table summarizes the approximate capital invest-
ment required to install wet limestone scrubbing at the eight
power plants in Iowa selected as potential candidates for
scrubbing:
Plant MW Capital Investment; $ $/KW
Des Moines 325 24,300,000 74.60
Maynard 107 16,200,000 151.10
Muscatine 117 11,300,000 96.90
Riverside 222 18,900,000 85.00
Burlington 212 14,300,000 67.40
N KapP 237 15,900,000 67.00
Prairie Creek 245 19,600,000 80.10
Sutherland 157 17,000,000 108.30
Total 1622 137,500,000 84.80 Average
The above figures assume that a thickener and small pond are
provided for sludge. If a large pond was installed at six of
the eight plants where space may be available (Des Moines,
Muscatine, Burlington, Kapp, Prairie Creek and Sutherland),
the investment cost would increase by about $7-12/kw depend-
ing on sulfur content of the coal.
Of the thirteen plants for which detailed capital cost estimates
were prepared, five were dismissed from consideration due to
their small size and hence burdensome costs (or due to space
limitations). These plants are Pella, Iowa State University,
Fair, Dubuque, and Lansing. The average cost for limestone
scrubbing for these five plants is $171.10/kw or about double
that for the other eight plants. No estimate was prepared for
the Sixth Street Station due to the unusually limited space
19
-------
at the site.
Estimates for the Wellman-Lord/Allied scrubbing system costs
were made using the M. W. Kellogg computerized cost model (3, pp.
110-129). They were made assuming the same degree of difficulty of
retrofitting this process as would be encountered with the
Wet Limestone process. The capital estimates are shown below:
Plant MW Capital Investment;$ $/KW
Des Moines 325 36,400,000 112.00
Maynard 107 18,400,000 172.50
Muscatine 117 14,900,000 127.10
Riverside 222 24,800,000 111.60
Burlington 212 18,800,000 88.50
Kapp 237 20,700,000 87.50
Prairie Creek 245 23,300,000 94.90
Sutherland 157 20.500,000 130.50
Total 1622 177,800,000 109.60 Average
The figures shown above indicate that in every case the Wellman-
Lord/Allied process is more costly than the Wet Limestone process
(by an average value of about $24-25/kw). Wellman-Lord/Allied
scrubbing systems also would not be feasible at the six plants
previously ruled out for Wet Limestone scrubbing for the same
reasons.
2. Capital and Operating Cost
Computerized cost models also were used to calculate capital
and operating costs for both the Wet Limestone process (3, pp.
83-98) and the Wellman-Lord/Allied process. The basic input data
for the programs are listed below:
HR = 11,000 Btu/KWH (Plant average heat rate)
HHV= 10,000 Btu/lb (Coal higher heating value)
20
-------
RBmax =1.7 (.Retrofit difficulty factors selected
RBase =3.5 to best match detailed cost estimates)
P =1.52 (Location factor)
LF =0.70 (Load factor)
CSL = $1.50/T (Wet Limestone process sludge
disposal cost)
The average capital investment predicted by the model for the
two processes (for the eight plants in Iowa) is as follows:
Wet Limestone $ 86.40/KW
Wellman-Lord/Allied 109.80/KW
Operating costs for the two processes are shown below:
$/MM Btu Input
Plant Gen:
Cap: MW
2%
W. L
34.3
32.7
Sulfur
. W-L/A
37.2
33.5
4% Sulfur
W.L. W-L/A
40.5 49.2
38.9 45.3
6% Sulfur
W.L. W-L/A
46.8 61.3
45.0 57.2
250
500
Based on the assumptions made, the Wet Limestone process is
less expensive to operate than the Wellman-Lord/Allied process
in all cases.
When processing flue gas from boilers burning very low sulfur
coal (1-2 % S), the processes are about equal in
cost.
As expected, as plant size increases, the operating cost in
C/MM Btu decreases.
The Wellman-Lord/Allied process is more sensitive to the sulfur
content in the coal than is the Wet Limestone process. For a
250 mw power plant, the increased operating cost for each 1%
sulfur increase is shown below:
21
-------
Wet Limestone 3.12C/MM Btu
Wellman-Lord/Allied 6.02C/MM Btu
The sludge disposal cost for the Wet Limestone process which
will bring its operating cost up to a figure equal to that
of the Wellman-Lord/Allied process is variable and depends
on the sulfur content of the coal. For a 500 mw plant burning
low sulfur coal (^ 2.5% S) this cost is about $2.44/ton of wet
sludge. For the same size plant burning high sulfur coal
(^5.% S), this cost is about $3.44/ton.
The higher operating costs for the Wellman-Lord/Allied process
(using high sulfur coals) can be explained solely by capital
charges on a considerably greater investment. There is much
more equipment associated with this process due to its complexity.
'The somewhat higher variable costs for chemicals, utilities, and
principally waste disposal for the Wet Limestone process are off-
set by lower labor charges.
For the Wet Limestone process, economics indicate that if sludge
disposal costs rise above about $1.50/T, then the installation of
a large pond would be indicated in order to limit disposal costs.
Sludge disposal for the Wet Limestone process presents a major
problem. The sludge is composed mainly of CaS04»2H20, CaSO_»1/2H_O,
unreacted CaCC>3/ and fly ash. The quantity produced (at 40% so-
lids) is about 15 tons per ton of sulfur removed from the flue gas
(4, p. 7). The size of a pond to hold 20 years of sludge produc-
tion is quite large. For example, a 250 mw power plant burning
5.0% sulfur coal would require a sludge pond 120 acres in area
x 50 feet deep (4, p. 79).
Solids disposal does not present as great a problem for the Well-
man-Lord/Allied process. Sulfur produced is assumed to have a
22
-------
credit (of $10/LT). This may be an oversimplification if the
sulfur supply-demand situation is studied. In 1985, the North
American demand for sulfur will probably reach about 17.5 MM
tons while the supply from traditional sources (Frasch process,
gas and oil desulfurization, and smelter acid) will be about
22 MM tons. Therefore it is obvious that the supply from existing
sources is more than adequate to meet the demand from traditional
sulfur consuming industries in 1985. If (by 1985) the utility
industry was consuming 500 MM tons/year of coal containing 3%
sulfur then an additional 15 MM tons/year of sulfur would be po-
tentially available. Clearly this would tend to lead to a con-
siderable oversupply of sulfur. However there are some potential
new uses for sulfur which may help to alleviate the problem. Some
of these are (17, pp. 239-243):
- Addition of sulfur to asphalt for use as a paving material
- Sulfur use in concrete
- Sulfur use as a bonding material
- Sulfur use as a coating material
A small quantity of purge solids also is formed in the Wellman-
Lord/Allied process. These solids (consisting mostly of sodium
sulfate and sodium thiosulfate) are. produced at the rate of about
0.30 tons/ton of sulfur removed from the flue gas (3, p. 121).
3. Stack Gas Scrubbing Evaluated in the Linear Program
Since the Wet Limestone process appears to be less costly then
the Wellman-Lord/Allied process, its operating costs were incor-
porated into the linear computer program. Two segments of the
Wet Limestone process operating cost were input into the program:
- The first is dependent on plant size
- The second is dependent on sulfur content of the coal
23
-------
The linear program could be modified to accommodate operating
costs for any other scrubbing process.
As discussed previously, stack gas scrubbing does not compare
favorably (in Iowa) with the use of low sulfur coal and/or coal
cleaning.
- At the 1.2 Ib S02/MM Btu specification, no stack gas scrubbing
is used if unlimited low sulfur coal is available. If low sul-
fur coal is limited, stack gas scrubbing is used in eight
plants.
- At the intermediate specifications (3.1 and 5.0 Ib S02/MM Btu),
no stack gas scrubbing is used. Emission standards are met by
using low sulfur coal and/or coal cleaning.
24
-------
G. Conclusions Pertaining to the Use of Western Coals In .Existing
Boilers
1. General
The conclusions reached in this study point to the use
of about 33 to 94%iwestern coals in Iowa boilers to meet
varying S02 emission regulations. The use of these western
coals in boilers and in pollution control devices (electro-
static precipitators) designed for indigenous and midwestern
coals may pose operational problems which will have to be
dealt with on an individual case basis. Of primary im-
portance are ash characteristics which determine the degree
of slagging and fouling which will occur in the boiler,
the bulk resistivity of fly ash passing through existing
electrostatic precipitator installations, and the abrasive-
ness of the coal.
2. Average Properties of Western Sub-bituminous Coals
The following table gives the range of properties of the
western sub-bituminous coals used in this study.
% Moisture 12.4 - 25.5
% Ash 4.2 - 10.0
% Sulfur 0.3 - 0.9
HHV (Btu/lb) 8790 - 11,460
Grindability (Hardgrove) 45-53
In general, the western sub-bituminous coals are low
in sulfur (below 1%); they are relatively high in
moisture and, therefore, relatively low in heating value;
they are high in volatile matter and have good ignition
characteristics.
25
-------
Of main concern to the boiler designers however, are the
ash characteristics. In this respect western coals run the
full spectrum.
3. Ash Slagging
Ash slagging refers to the ash deposits that form on
surfaces in the furnace exposed to radiant heat (10, p.
2). The ash fusion temperature of a given coal provides a
rough indication of the potential furnace wall slagging
problems which may occur. Generally boilers which use coals
with high ash fusion temperatures will remain dry with little
or no deposit on the furnace wall. Slagging is usually
meant to be the physical transport of molten or sticky
ash particles and the subsequent formation of dense hard
deposits on the radiant tubes (11, p. 3). Most coals
have low to intermediate ash fusion temperatures; hence
boiler designers must rely largely on slag viscosity
characteristics of lignite type ash to predict slagging
tsndencies in boilers (18, p. 9). Coals with low ash
viscosity characteristics tend to cause excessive slagging
(18, p. 3). If the information is available, the viscosity
of the coal ash slag is used as a guide in furnace design
of a steam generator. When the viscosity of the ash is
not known, however, it has been necessary to derive
slagging indices based on ash analysis and furnace
observation. One such slagging index (Rg) has been de-
veloped which divides the slagging characteristics of coal
into four different categories as shown below (11, p. 11).
1^
Slagging Type Slagging Index; S
Low Less than 0.6
Medium 0.6 - 2.0
High 2.0 - 2.6
Severe Greater than 2.6
26
-------
Based on the relative slagging index the furnace design
may be modified to consider such items as burner input
vs. furnace size, burner clearances, furnace exit gas
temperatures, and the number and location of furnace
wall blowers for the most effective removal of slag
(11, pp. 11-12).
4. Ash Fouling
Ash Fouling refers to bonded deposits that form at
high temperatures on convection tube banks, especially
the superheater and reheater which are not exposed to
direct radiant heat from the furnace (11, p. 2). The
high temperature bonded deposits are generally caused
by volatilization of elements from the ash and selective
condensation and deposition upon the convection tube
surfaces as well as by impaction of ash on the tubes.
The amount of ash in the coal frequently has little
influence on ash fouling. More important is the behavior
of the ash minerals when they are subjected to high tem-
peratures during combustion of the coal (11, p. 4).
The first constituents identified as contributing to
deposit strength are the alkali metals, sodium and potas-
sium (10, p. 2). Generally the sodium oxide and calcium
sulfate content of the ash is used to predict fouling
tendencies in the convection passes (18, p. 6).
A fouling index R^ has been devised dividing coal into
four categories (11, p. 12).
Fouling Type Fouling Index ;^
Low Less than 0.2
Medium 0.2 - 0.5
High 0.5 - 1.0
Severe Greater than 1.0
27
-------
9 Some of the boiler design parameters which may be changed
to mitigate the relative fouling tendency of the coal are
the flue gas temperature, back-spacing and side-spacing of
tubes, slope of superheater and reheater floor and
clearances under pendant sections, number and location of
soot blowers, cleaning radius of soot blowers, and tube
bank depths. For example, if it is expected that the coal
to be fired will produce hard massive deposits (Rp=
1.0 or higher) the pendant superheater sections are de-
signed to permit easy deposit removal. Lateral tube spacing
is increased, tube bank depth is decreased, and the banks
are located in cooler gas temperature zones. A greater
number of high capacity soot blowers will be required
(11, p. 13).
5. Relative Abrasiveness of Sub-bituminuous Coal
An important characteristic of a coal is its relative
abrasiveness. This property may affect the life of
grinding equipment (pulverizers) by a factor of 5-10
to 1. Abrasiveness is a separate characteristic of coal
apart from the grindability. The abrasiveness of a coal
depends largely upon the amount of quartz or other hard
materials associated with the impurities, while grind-
ability is determined primarily by the structure of the
organic materials. In abrasiveness also, the western
sub-bituminuous coals run the full spectrum from high to
low (18, p. 3).
6. Electrostatic Precipitator Performance
Ironically the low sulfur content of western coals which
makes them so attractive may cause problems with particulate
collection in the electrostatic precipitators. Two of
the important para-meters in determining the efficiency
28
-------
of an electrostatic precipitator are the residence time and the
resistivity of the fly ash. Performance drops off with increased
resistivity (due to lower sulfur content) and with decreased
residence time.
One approach used to improve efficiency is to make the electro-
static precipitators larger, hence decreasing the velocity
which will compensate for the change in resistivity. This
approach is expensive, however, because the electrostatic
precipitators must be increased in size. It would be very
impractical for existing units which are already in service.
A second approach used is to locate the electrostatic precipitator
in the hot gas zone upstream of the air preheater (where the
resistivity of the fly ash is lower) thereby regaining the fly
ash removal efficiency. Using this technigue means treating a
greater gas volume and makes the electrostatic precipitators
larger and more expensive (10, p. 3). This approach is also
impractical for existing cold side units.
The third approach used to restore electrostatic precipitator
efficiency is the conditioning of the flue gas with a small
quantity (15-20 ppm) of S03 to lower the resistivity of the
fly ash. When sulfur content in the coal is low the resistivity
of the fly ash particles is high (at normal air heater outlet
temperatures) and it is difficult for them to accept a charge
and be attracted to a plate in the electrostatic precipitator.
Conditioning the gas produces a lower resistivity of the fly
ash particles and restores the electrostatic precipitator effi-
ciency (13, pp. 50-53). This is the recommended approach for
the Iowa power plants when burning low sulfur western coal.
29
-------
IIL OVERALL SYSTEM EVALUATION
The State of Iowa currently has some 35 power plants which burn
coal with a total installed generating capacity of 3093 mw.
Though many of the boilers in these plants have previously burned
some natural gas and fuel oil, the assumption was made for this
study that the energy requirement for each plant will be met ex-
clusively with coal. Indeed, the projected use of coal in 1975
will total 79.1% of the state's utility fuel requirement and in
1980 will total 89.0% (1, p. 326).
Coal used in Iowa utilities comes from a number of states (Iowa,
Illinois, Kentucky, Kansas, Oklahoma, Wyoming, and others).
There are many mines in each state which can supply coal. In
addition, there are many different methods (and different costs)
of transporting the coal from the mines to the power plants
(truck, rail, unit train and barge or some combination of these).
Also, the coal may travel over different routes. The purchased
price of each coal varies as does its properties (% ash, % sulfur,
HHV, and % moisture). The cleaned properties of each coal also
vary.
When coal is burned in utility power plants, the sulfur originally
in the coal (whether present as pyritic sulfur, organic sulfur, or
sulfate) is converted to S02 and S03 (100% conversion to S02 was
assumed in this study) which then flows out of the stack in the
flue gas. A number of different maximum emission levels of SO?
(Ib S02/MM Btu input) are being considered. The least stringent
regulation, of course, would be no control and the most stringent
regulation would be the Federal new-source regulation of 1.2 Ib
SO7/MM Btu. There are also some intermediate regulations being
considered.
30
-------
How does a utility control the amount of S02 being emitted to meet
a given regulation? Three methods or some combination of them were
chosen in this study:
- the use of low sulfur coal
- coal cleaning
- stack gas scrubbing
To further compound the problem, the number, size and locations of
the cleaning plants and scrubbing systems can vary.
To evaluate a system of such complexity, M. W. Kellogg devised a
linear computer program. The program minimizes the overall system
cost while delivering the required amount of coal to each power
plant and while meeting any one of a number of different SO- emission
speci fications.
A. Basic Assumptions Made for the System to Use in the Linear
Computer Program
1. Power Plants Considered
In order to limit the size of the problem, it was necessary
to limit the number of power plants considered in this
study. A total of eighteen power plants having an installed
generating capacity of 2737 mw (88.5% of the total) was
used. The following table lists these power plants, their
generating capacity, and their energy requirements in
MM Btu/D.
Location Code*
Class PL Plant Location MW MM Btu/D**
DA Ames (Ames Municipal Plant) 60 18,684
DB Ames (Iowa State University) 25 12,994
DC Montpelier 63 17,726
DD Lansing 64 20,023
DE Dubuque 74 24,504
DF Clinton 237 59,525
DG Cedar Rapids (Prairie Creek) 245 64,862
DH Cedar Rapids (6th Street) 92 64,937
DI Marshalltown 157 43,219
* Refer to Section VII of this report
31
-------
Class PL Plant Location MW MM Btu/D**
DJ Bettendorf 222 67,512
DK Council Bluffs 131 33,461
DL Des Moines 325 87,017
DM Waterloo 107 31,570
DN Salix 491 115,682
DO Eddyville 71 25,608
DP Burlington 212 51,307
DQ Muscatine 117 31,488
DR Pella 44 18,259
Total 2737 788,378
** @ 100% generating capacity (a 65-70% load factor for these
plants would more nearly approximate the actual Iowa coal requirement)
*** Included because of high heat rate due to exporting heating steam
Generally speaking, power plants with a generating capacity
of about 40 mw or less were eliminated from consideration
in this study. Some seventeen plants comprising about half
of the total number of plants in the state but only about
11.5% of the generating capacity were thus eliminated. Con-
clusions reached in the study however (which include coal
cleaning or low sulfur coal blending), may be extended to
include the small power plants.
2. Coal Mine Selection
The following tables list the eight coal mines which were
selected for this study. The tables also list the mined coal
properties, costs, mine capacities, and clean coal properties.
Raw Coal
Location
Class ML
MA
MB
MC
MD
ME
MF
MG
MH
Code
Location
Frederick, Iowa
Leon , Iowa
Ogden , Iowa
Marion, 111.
Madison vi lie , Ky .
Hanna , Wy .
Craig, Col.
Colstrip, Mont.
% Ash
14.2
12.8
13.2
14.9
14.8
8.4
4.2
10.0
Properties
% Sulfur
5.9
4.3
6.9
3.1
4.1
0.9
0.3
0.8
Btu/lb
10,038
9,676
10,184
11,951
11,801
10,506
11,460
8,790
Cost:
$/T
6.25
6.25
6.25
6.70
6.70
4.20
5.00
3.60
Mine
Capacity
MT/D
<
»
H
M
cn
32
-------
Cleaned Coal Properties*
Location Code
Class ML .
MA
MB
MC
MD
ME
% Ash
7.9
7.0
7.5
7.0
7.2
% Sulfur
3.5
1.9
4.5
2.0
2.7
Btu/lb
11,033
10,650
11,166
12,505
12,340
Loss : %
20.0
20.0
20.0
20.0
20.0
Selection of the coal mines to provide coal for the Iowa
Utility Industry was based primarily on the report submitted
by the Gates Engineering Company (2, pp. 7-9). Ten potential
mines were presented in the report for the State of Iowa.
From this group three were selected as being representative
of the Iowa coal supply (2, p. 14). For the State of Illinois
the average properties of the No. 5 and No. 6 seams from
Marion, Illinois were used in the study (2, p. 8).
The Kentucky coal used in the study is from Madisonville,
Kentucky. The average properties of the No. 6, No. 9, No. 11,
and No. 12 seams from Madisonville were used (2, p. 8). A
number of potential mine sites were given in the Gates report,
Appendix C, in Wyoming, Colorado, and Montana. From this list
one mine site considered to be representative was selected for
each state. The three choices were Hanna, Wyoming; Craig,
Colorado; and Colstrip, Montana.
The coal prices (FOB mine) also were furnished in the Gates
report. In Iowa, Illinois, and Kentucky the coal was assumed
to be 40% strip mined and 60% deep mined. The western coals
were considered to be 100% strip mined. Each ton of strip
mined coal has a 70* transfer charge added to transport the
coal from the mine to the rail site. Coal prices are given
in the Gates report (2, p. 1).
Coal properties which can be achieved by a coal cleaning
plant with 80 weight % recovery.
33
-------
The following calculations show how the coal pithead costs
were computed.
% strip mined (strip mine cost) + % deep mined (deep mine
cost) + % strip mined (strip mine transfer charge) = total
Iowa Coal
0.4 (4.85) + 0.6 (6.70) + 0.4 (0.70. = $6.24 (Use $6.25/T)
Illinois Coal & Western Kentucky Coal
0.4 (5.25) + 0.6 (7.20) + 0.4 (0.70) = $6.70/T
Wyoming Coal
3.50 + 0.70 = $4.20/T
Colorado Coal
(3.90 + 4.70) = 4.30 4.30+0.70 = $5.00/T
2
Montana Coal
8790 (3.50) = 2.93 2.93 + 0.70 = $3.63/T (Use $3.60/T)
10506
It was assumed that the five high sulfur coals used in the
study could all be cleaned to the 80% recovery level. This re-
covery level is shown to be about optimum from the Gates report
(2, pp. 14-16) for the Iowa coals. The same recovery level of
80% also was chosen for the Illinois and Kentucky coals. Note
that no cleaning was permitted for the western coals since these
fuels are already very low in sulfur content and fairly low in
ash content.
3. Potential Other Possible Transfer Points (in addition to the mines
and power plants)
The following is a list of other possible transfer points:
Class OL
PA Paducah, Kentucky
PB Gorham, Illinois
34
-------
Paducah, Kentucky is located on the Ohio River, 85 miles
by rail from Madisonville, Kentucky. A logical method of
shipment would be by standard rail from Madisonville to
Paducah and then by barge on the Ohio and Mississippi
Rivers to the power plants. Gorham, Illinois was chosen
as a possible transfer point because it is the closest
point on the river from the Marion, Illinois mine. Again
a logics1 shipping method would be to ship coal by standard
rail from Marion, Illinois to Gorham and then by barge on
the Mississippi River to the Iowa power plants.
4. Potential Scrubbing Locations
The following plants were chosen as potential sites for
scrubbing facilities:
Class SL Plant Location
DF Clinton
DG Cedar Rapids (Prairie Creek)
DI MarshalItown
DJ Bettendorf
DL Des Moines
DM Waterloo
DP Burlington
DQ Muscatine
Ten of the eighteen power plants used in the study were
not considered for stack gas scrubbing due to either the
small generating capacity of the plant, overcrowded
conditions existing at the plant, or previous committments
for low sulfur fuel by the plant.
5. Potential Cleaning Locations
The following is a list o'f possible coal cleaning plant
locations chosen in the Iowa study:
35
-------
Class CL Location
DN Salix, Iowa
DP Burlington, Iowa
MA Frederick, Iowa
MB Leon, Iowa
MC Ogden, Iowa
MD Marion, Illinois
PA Paducah, Kentucky
PB .Gorham, Illinois
It was necessary to reduce the number of possible cleaning
locations in order to greatly minimize the number of
calculations to be performed by the computer. The logical
cleaning plant locations are at the mines since there is
a 20% material loss at the cleaning plant resulting in
considerably lower freight rates from the mines to the
power plants. Four other possible cleaning locations (DN,
DP, PA, and PB) were also selected.
6. Summary of Loading/Unloading Facilities
All power plants, mines and the two other locations were
assumed to have standard railroad facilities. In addition,
unit train facilities were assumed to be present at DN,
DP, MD, ME, MF, MG, and MH. Barge loading/unloading
facilities were assumed to be present at the seven Iowa
power plants located on the Mississippi River (DC, DD, DE,
OF, DJ, DP, and DQ). Also, barge loading facilities were
assumed to be present at PA and PB.
7. Specifications
The following list includes the four specifications that
the program was run for:
36
-------
Table Specification
1 20.0 Ib SO2/MM Btu (No emission control)
2 5.0 Ib S02/MM Btu
3 3.1 Ib S02/MM Btu
4 1.2 Ib S02/MM Btu
Note that the model can be easily adjusted to run any other
specification as long as it is uniform statewide or systemwide.
8. Summary of Economic Factors
Rate Basis
Standard Rail $0.0'28/T-M Iowa Util. Avg. Rate
Unit Train $0.005/T-M (1, p. 435)*
Barge $0.006/T-M (2, p. 21)
Ash Disposal at Pwr. Plant $1.00/T Iowa Utilities
Refuse Disposal at Clng. Plant $0.31/T (2, p. 21)
Storage/Transfer Cost $0.30/T (2, p. 21)**
Cleaning Plant Oper. Cost $1.90/T (2, p. 13)***
*Supplemented by information from Union Pacific Railroad
**Applies to any coal shipment which goes through an inter-
mediate point (either a transfer point or a cleaning plant)
***Adjusted to include profit, depreciation, and interest.
9. Distances by Rail
The distances between all points are tabulated in the
Table RRDIST which forms a symmetric matrix half of which
is entered as a triangular table. The 1973 Railroad Atlas
was used to compute the minimum distances between all
points (8). In many cases, calculating the minimum distance
between two points meant transferring from railroad tracks
owned by one railroad company to tracks owned by another
company. This operation was assumed to present no problem
for the study.
37
-------
10. Distances by River
A separate table (Table RIVERD) was supplied to give the
river mileages between all points located on the Mississippi
and Ohio rivers. This table is to be used in calculating
barge transportation costs. The points included in this
table are power plants DC, DD, DE, DF, DJ, DP, and DQ and
other locations, PA, and PB.
11. Cost of Washing and Scrubbing
As indicated above, the coal cleaning plant operating cost
used in this study is $1.90/ton of feed coal. The minimum
cleaning plant size used is one capable of processing
7200 t/d of feed coal. The cost of stack gas scrubbing
(using the Wet Limestone process) is made up of two parts.
The first is the non-linear cost which is related to plant
size; the second is the linear cost related to the sulfur
content in the feed coal. These costs are broken down
more fully in Sections VI and VII. The minimum size
scrubbing facility considered is one which would be
applicable for a 50 mw boiler.
B. Linear Computer Program Results
The following tables summarize the results for the three
cases studied for Iowa. The following items are shown in
the tables for each of the sulfur dioxide emission levels
(20, 5, 3.1, and 1.2 Ib/MM Btu):
- All of the components which comprises the totel system
cost (coal pithead cost, freight cost, ash disposal
cost, scrubbing cost, coal washing cost, refuse dis-
posal cost, and coal storage/transfer cost).
- The incremental system cost over no sulfur dioxide
38
-------
control
The quantity of coal used from each mine
The numbar of stack gas scrubbing systems used.
The number of coal cleaning plants used
Following the tables is Figure 1 which is a plot of the in-
cremental system cost in C/MM Btu vs. the sulfur dioxide
emission level in lb/MM Btu.
39
-------
Table 1
CASE 1
8 Possible Scrubbing Locations
8 Possible Cleaning Locations
System Cost ; $/D
TFRT
TASH
TSC1
TSC2
TWSH
TREF
TSTO
Cost Total
A Cost Over Spec 20 : $/D
A Cost Over Spec 20 : C/MM
Coal Source ; T/D
MA
MB
MC
MD
MB
MF
MG
MH
Total
Scrubbing Systems
Cleaning Plants : T/D
IOWA STUDY
788,400 MM BtU/D
ons Unlimited Western Coal
ms Unlimited Illinois Coal
Spec : Ib SO2/MM Btu
20
219,517
90,935
4,774
3,249
318,475
Btu -
8,650.4
9,499.4
11,383.4
7,098.0
36,631.2
None
None
5
205,165
141,749
4,198
7,071
358,183
39,708
5.04
508.4
2,406.4
534.4
19,741.5
7,683.5
3,813.7
34,687.9
None
None
3.1*
185,502
188,100
3,301
7f672
384,575
66,100
8.38
292.6
1,385.0
307.6
9,978.6
13,605.7
9,818.6
35,388.1
None
None
1.2
171,510
232,085
2,129
8,120
413,844
95,369
12.10
76.8
363.6
80.8
1,622.3
10,193.0
22,914.6
35,251.1
None
None
DK, DN Below Specification
** Refer to pages 240-241
-------
Table 2
CASE 2
IOWA STUDY
8 Possible Scrubbing Locations
8 Possible Cleaning Locations
System Cost : $/D
Limit = 16,
Unlimited
Spec :
20
TPIT 219,517
TFRT
TASK
TSCI
TSC2
TWSH
TREF
TSTO
90,935
4,774
_
-
-
_
3,249
Cost Total 318,475
A Cost Over Spec 20
A Cost Over Spec 20 : C/MM Btu
Coal Source : T/D
MA
MB
MC 9
MD 11
ME
MF 7
MG
MH
Total 36
Scrubbing Systems
Cleaning Plants : T/D
-
-
8650.4
-
,499.4
,383.4
,098.0
-
,631.2
None
None
000 T/D Western Coal
Illinois Coal
Ib SO,/MM Btu
5
205,165
141,749
4,198
_
-
-
7,071
358,183
39,708
5.04
508.4
2406.4
534.4
19,741.5
7683.5
3813.7
~
34,687.9
None
None
788,400 MM
(8,000 T/D
3.1
207,110
160,788
3,356
-
-
14,230
464
8,660
394,608
76,133
9.66
_
7489.5
-
12,940.4
8000.0
8000.0
~
36,429.9
None
CC1MB = 7489
Btu/D
Hanna, 8,000 T/l
1.2
199,517
159,133
3,762
116,356
39,327
7,017
525,112
206,637
26.21
_
4171.0
14,902.7
~
8000.0
8000.0
" ~
35,073.7
All 8 plant:
None
-------
Table 3
CASE 3
8 Possible Scrubbing Locations
8 Possible Cleaning Locations
System Cost ; $/P
TPIT
TFRT
TASH
TSC1
TSC2
TWSH
TREF
TSTO
to Cost Total
A Cost Over Spec 20 : $/D
A Cost Over Spec 20 : C/MM Btu 1.03
Coal Source i T/D
MA
MB
MC
MD
ME
MF
MG
MH
Total
Scrubbing Systems
Cleaning Plants : T/D
ns
s Limit -
Limit"
20
220,504
99,144
4,784
2,163
326,595
8,120
itu 1.03
11,258.4
11,142.2
7000.0
8000.0
37,400.6
None
None
IOWA STUDY
16,000 T/D Western Coal
7,000 T/D Illinois Coal
Spec :lb SO,/MM Btu
111 5
211,067
146,210
3,471
13,680
446
6,808
381,682
63,207
8.02
5404.1
7200.0
1886.6
7006.0
8000.0
8000.0
37,490.7
None
CC1MB = 7200
788,400 MM BtU/D
(8,000 T/D Hanna, 8,000 T/D C:
(7,000 T/D Marion)
3.1
217,964
156,680
3,019
27,357
893
9,064
414,977
96,502
12.24
338.1
14,398.4
857.8
7000.0
8000.0
8000.0
38,594.3
None
CC1MB 14,398
1.2
211,340
148,898
3,489
113,448
45,565
13,680
446
6,968
543,834
225,359
28.58
6885.0
7649.4
7000.0
8000.0
8000.0
37,534.4
All 8 plan
CC1MB = 721
-------
Figure 1
INCREMENTAL SYSTEM COST VS. SO2 EMISSION SPECIFICATION
30
D
m 20
1
UJ
01
OC
O
10
CASE 1
8
EMISSION SPECIFICATION: LB SO2/MM BTU
-------
IV PROCESS DESCRIPTIONS
A. Flue Gas Scrubbing Processes
1. Wet Limestone System (Refer to Appendix B)
a. General
This task specified that two types of stack gas
scrubbing processes for S0~ removal be evaluated:
- a throw away system
- a regenerable system
The throw away process selected for S0_ removal is
the Wet Limestone process. The process design for the
Wet Limestone system is based on the design proposed
by the Tennessee Valley Authority for their Widow's
Creek Unit 8 SO- removal process. This design was
used because it incorporates up-to-date technology
regarding wet limestone scrubbing. However some minor
departures from the TVA design were taken in both the
limestone handling system and the scrubbing system.
i
b. Limestone Handling, Grinding and the Effluent System
This system is designed for receiving limestone by
both rail and truck from the limestone quarries.
Limestone is unloaded into a 100 ton hopper, 101-F,
located in a concrete pit below grade. The hopper
is sized to accomodate unloading of railroad cars
as well as trucks. The limestone is transferred
from the hopper via a feeder, 101-V, to the tunnel
belt conveyor, 102-V, which transfers the limestone
44
-------
to either the stacker, 103-V, feeding the dead
storage pile or to the plant conveyor, 104-V, which
feeds the live storage silos via the tripper belt,
105-V.
The limestone system for each plant is designed for
running the power plant at peak capacity using coal
containing the maximum sulfur content (highest
monthly average for 1972) . Limestone flow rate is
based on 150% of the stoichiometric quantity re-
quired. Design capacity for the feeder, conveyors,
stacker and tripper is five times the maximum lime-
stone consumption rate to allow for receiving lime-
stone in a 40 hour week while the plant operates
continually. A limestone dead storage pile is sized
for 30 days usage (in the event of an interruption
in the supply of limestone) and the live storage silos,
102-F, are sized to hold 3 days supply (to allow
the plant to operate over a 3 day weekend without
receiving limestone). The live storage silos and
ball mills are located in an enclosed building,
101-K, to preclude weather and fugitive dust
problems.
Limestone is fed from the live storage silos to the
wet ball mills, 101-L, where it is ground in closed
circuit from the purchased size (3/4" x 0") to the
final size (90% minus 200 mesh). The slurry from
the ball mills (about 65% solids) is fed to the
cyclone classifiers. Underflow from the classi-
fiers containing oversized particles is recycled to
the ball mills for regrinding.
Overflow from the cyclone classifiers flows to a
45
-------
mill slurry sump where sufficient water is added to
reduce the solids concentration to 40%. Mill sump
pumps are used to transfer the 40% limestone slurry
to the limestone slurry surge tank, 103-F.
Three 33% capacity ball mills are used in each plant
(based on the maximum limestone flow) allowing two
mills to handle the normal limestone requirement.
The limestone slurry surge tank is a carbon steel
rubber-lined vessel with an agitator. It has a
capacity corresponding to 4 hours storage (at maxi-
mum limestone flow), allowing the scrubbing trains to
continue operating while maintenance is being done in
the grinding area.
Limestone is fed to the scrubbing trains by rubber-
lined centrifugal limestone slurry feed pumps, 101-J.
One pump is used for each individual scrubbing train
with a spare provided for each three operating pumps.
Effluent slurry containing about 15% solids flows
from the venturi scrubber circulating tanks to the
effluent slurry surge tank, 104-F, which is a
rubber-lined carbon steel vessel with an agitator.
It is sized for 5 minutes storage capacity. Rubber-
lined centrifugal pumps, 104-J, send the slurry
to a thickener, 102-L, which concentrates the solids
i
to about 40%. Recycle water pumps, 103-J, return
overflow water from the thickener to the scrubbing
trains and the ball mills. Net make-up process
water requirements comprise that which is evaporated
into the gas while cooling it in the venturi scrubber
and that which is lost in the sludge. This water
is supplied by the raw water pumps, 102-J.
46
-------
Sludge is sent from the thickener to a relatively
small lined holding pond. The ponds are sized to
hold about 2 weeks production of sludge. The solids
portion of the sludge consists mainly of hydrates of
calcium sulfite and calcium sulfate, unreacted lime-
stone, and fly ash. Net sludge produced will have
to be removed from the plant site via truck, rail,
or barge.
Alternatively the thickener can be eliminated and a
large settling pond used. However, lack of land pre-
cludes using this disposal method in most cases. For
example, a 500 MW plant burning 5% sulfur coal would
require a 241 acre by 50 feet deep pond to hold 20-
years production of sludge.
Wash water is pumped from a settling pond (fly ash
pond) to the entrainment separators by the wash water
2
pumps, 106-J, at the rate of 1 gpm/ft of CSA. En-
trainment separator pumps, 105-J, return this water
to the pond.
c. Scrubbing System
Flue gas leaves the electrostatic precipitators of the
power plant boilers at essentially atmospheric pressure
o
and at a temperature of about 300 F (ranges from
o
250 - 350 F). It has a fly ash loading of about 2-5
grains per actual cubic foot (gr/acf) entering the
precipitators. The fly ash loading leaving the pre-
cipitators will be about 0.4-1.0 gr/acf (wet) assuming an
efficiency of 80%. The S02 content of the flue gas will
range from about 1650 to 3300 ppm (wet) with coal having
an initial sulfur content of 2.5-5.0%.
Eight standard sized scrubbing trains were designed
47
-------
for use in this study. The largest train will treat
about 545,000 acfm (hot gas) corresponding to about
167-182 mw. This is currently the largest unit being
built by UOP. The smallest train will treat about
91,000 acfm which corresponds to about 28-30 mw. Each
scrubbing train consists of a fan, venturi scrubber,
venturi scrubber circulating tank and pumps, absorber,
u
absorber circulating tank and pumps, an entrainment
separator, and a reheater.
Flue gas from the existing electrostatic precipitators
enters the fan, 203-J, in a scrubbing train. The fans
are double inlet centrifugal units equipped with
variable speed fluid drives. Each fan is designed
for a pressure differential of 25" E^O and a flow
rate 10% above normals. The fans supply the motive
power for the scrubbing system.
A venturi scrubber, 201-E, is used to cool, saturate,
and remove residual fly ash and some SO^ from the
flue gas. The unit is designed for a pressure drop
of 10" H20 and a fly ash removal efficiency of about
99%. S0_ removal in the venturi scrubber is expected
to be about 20-30%. The venturi scrubber is con-
structed of 316 L stainless steel with an abrasion
resistant lining and has a rectangular throat with a
motor operated variable throat mechanism. Velocity
in the throat is in the range of 200 fps. Constant
speed rubber-lined centrifugal pumps, 201-J, are used
to pump slurry (15% solids) from the venturi scrubber
circulating tank, 201-F, to the venturi scrubber.
Two pumps are provided per train - one operating and
one spare - and are designed to supply liquid to the
venturi scrubbers at a rate of 16.1 gpm/mscfm of in-
let gas (11 gpm/macfm hot gas). The venturi scrubber
48
-------
circulation tanks are rubber-lined carbon steel
vessels provided with agitators, 201-L. They are
designed for a retention time of 5 minutes (85%
full) based on the venturi circulation rate. This
design is similar to that used by Catalytic, Inc.
(15, pp. 23-24).
Saturated gas from the venturi scrubbers (at 125°F)
flows to the absorbers, 202-E. These units are UOP*
Turbulent Contact Absorbers (TCA's). The absorbers
are rubber-lined carbon steel vessels with 316 SS in-
ternals containing 3 beds of hollow 1-1/2" diameter
thermoplastic spheres. Each bed has a static ball
depth of 12" and the beds are spaced 4 feet apart.
The absorbers are designed for a superficial gas
velocity of 12.5 fps. They are rectangular in cross
section with the largest unit being 15' x 40' and
the smallest being 15' x 6.67'. Overall height of
the absorbers from the bottom of the hopper is 45'.
Expected SO2 removal efficiency in the absorber is
about 87% of the remaining SO~ in the gas from the
venturi giving an overall SO- removal efficiency of
90%. Pressure drop through the absorber is expected
to be 7" H20.
Rubber-lined centrifugal pumps, 202-J, equipped with
variable speed fluid drives are provided to pump
slurry (containing 10% solids) from the absorber
circulating tank, 202-F, to the absorber. Three
pumps are provided per scrubbing train - two oper-
ating and one spare. The pumps are designed to supply
slurry to the absorbers at a rate of 64.5 gpm/mscfm
of inlet gas to the venturi. This corresponds to
2
about 44.2 gpm/macfm of hot gas or about 40 gpm/ft of
CSA. Design of the unit is based on information from
TVA and UOP.
*UOP: Universal Oil Products Company (Air Correction Division)
49
-------
Gas from the entrainment separator is heated from 125 F
to 175°F in the reheater, 201-C, to desaturate and provide
buoyancy for the gas. This unit is an indirect tubular ex-
changer utilizing saturated steam at 500 psig. Estimated
pressure drop in the unit is 4" H20. The first 30% of the
rows of tubes are constructed of Alloy 20 for corrosion re-
sistance to the gas which enters at its dew point. The
remaining 70% of the rows are constructed of carbon steel.
A reheat AT of 50°F was chosen in this study because it is be-
lieved to be about the minimum acceptable value. Note that
each 50°F increase of the flue gas temperature requires about
1.3% of the gross heat input into the plant.
Steam operated soot blowers are provided at locations
where solids deposition is expected to occur. Soot blowers
are placed in the inlet duct to the venturi, 203-L, in the
elbow between the absorber and the entrainment separator,
204-L, and at the reheater, 205-L.
Gas leaving the reheater flows to the stack. Positive
shut-off guillotine gates are provided at three locations -
the inlet to the fan, the exit from the reheater, and a
by-pass connecting the inlet and outlet ducts. These gates
will make maintenance possible on one scrubbing train while
the remainder of the trains continue operating.
Fresh limestone slurry, water recycle, and make-up water
are added to the absorber circulating tank. Limestone
is fed at 150% of the stoichiometric rate and water is added
in sufficient quantity to maintain the solids concentration
at about 10%. Overflow from the absorber circulating tank
goes to the venturi scrubber circulating tank. The solids
concentration in this tank will depend on the inlet flue gas
fly ash loading but will normally run about 15%. Overflow
from each venturi scrubber circulating tank goes to the
effluent slurry surge tank as described previously.
50
-------
Clean flue gas flowing to the stack will have a fly ash
loading of about 0.01-0.02 gr/acf (wet) and an SO content
of about 160-320 ppm based on 90% removal in the scrubbing
train.
51
-------
2. Wellman-Lord Process
a. Scrubbing Section (Area 100)
The Wellman-Lord scrubbing system is designed to reduce
the S02 content in power plant flue gases to an accept-
able level for discharge to the atmosphere.
Flue gas from the boiler enters a booster fan, 101-J,
which sends the gas through the system. The gas enters
the absorber, 101-E where it is first pre-scrubbed with
recirculating water to remove residual flyash. The
water is circulated by the prescrubber circulating
pumps, 103-J. The solids content in this stream is
controlled by purging a small slipstream to the exist-
ing flyash disposal pond. Fresh make-up water is added
in the prescrubber section. Cool, saturated gas at
about 130°F is then contacted countercurrently with
a sodium sulfite solution in the top section of the
absorber for removal of SO . The Na_SO_ solution chemically
absorbs S0_ by the reaction:
S02 + Na2 S03 + H20 -» 2 NaHS03.
The sodium sulfite solution is circulated through the
absorber via the absorber circulating pumps, 104-J.
Gas leaves the absorber after passing through a mist
eliminator and flows to a reheater, 101-C. The temperature
of the gas stream is raised to about 175°F to desaturate
the gas and provide buoyancy for it. Clean flue gas
containing only 5% of the initial S02 then flows to the
stack.
Another reaction which may occur to some extent in the
absorber when S0_ is present in the gas is the following:
52
-------
2Na2
Also some oxidation of the sodium sulfite solution
may occur.
1/2
The bisulfite rich solution (NaHSO-J is withdrawn
from the bottom of the absorber and is sent to the
abosrber surge tank, 101-F.
b. Regeneration Section (Area 200)
Bisulfite rich liquid is pumped from 101-F through
the flyash filters, 201-L, via the filter feed pumps,
201-J. From the filters, most of the liquid flows to
the evaporator feed tank, 201-F. However, a small
quantity is sent to the Purge/Make-up Section for
sodium sulfate extraction.
The evaporator feed pumps, 203-J, send the solution
to the evaporator, 202-F. Liquid is circulated
through the evaporator heater, 201-C, by the evaporator
circulating pumps, 205-J. The solution is heated in an
indirect heat exchanger using low pressure steam. As the
solution boils, SO_ and H_O vapor are released and sodium
sulfite crystals precipitate from the solution. The
reaction occurring in the evaporator is:
2NaHS03 * Na2S03 + + S02 * + H^Q t.
A heavy slurry of undissolved solids is maintained in
the evaporator circuit by withdrawing part of the slurry
and sending it to the dump/dissolving tank, 203-F.
53
-------
Overhead gas from the evaporator flows to the primary
condenser, 202-C, where water vapor in the gas is
partially condensed. Gas leaving the primary condenser
joins overhead gas from the condensate stripper and feeds
the secondary condenser, 203-C, where most of the remain-
ing water vapor is condensed. Cooling water is circulated
through both the primary and secondary condensers. Con-
densate from both the primary and secondary condensers
flows to the condensate stripper, 201-E. In this packed
column, the condensate is stream stripped to remove any
dissolved SO-. The condensate from the stripper is used
for redissolving the sodium sulfite crystals in the dump/
dissolving tank. It is pumped through the condensate
cooler, 205-C, via the condensate stripper pumps, 209-J,
to 203-F.
SOj vapor from the secondary condenser flows through a
knock-out drum and then to the S02 superheater, 204-C,
where it is heated and then compressed by the S02 com-
pressor, 210-J, and sent to the sulfur plant (Area 400).
Regenerated sodium sulfite (Na, S03) solution from the
dump/dissolving tank is pumped to the absorber feed tank,
204-F, via the transfer pumps, 207-J, and is then returned
to the absorber (Area 100) via the absorber feed pumps,
208-J.
Soda ash (Na,CO,) make-up solution is added to the dump/
^ J
dissolving tank where it reacts with sodium bisulfite to
form additional sodium sulfite solution:
2NaHS03
54
-------
c. Purge/Make-up Section (Area 300)
The purge/make-up section is designed to remove inert
compounds such as sodium sulfate and sodium thiosulfate
from the liquids and return sodium sulfite/bisulfite back
to the S02 revovery unit. A side-stream is taken from the
evaporator feed for sodium sulfate purge and another side-
stream is taken from the dump/dissolving tank for sodium
thiosulfate purge. The purge compounds are removed as
dry solids after processing and sodium sulfite/bisulfite
solution is returned to the evaporator.
55
-------
Allied Chemical Process for SO Reduction
In the Allied Chemical process, SO. produced in the Wellman-
Lord process is reduced to elemental sulfur. Natural gas
is used as the reducing agent. The natural gas is mixed with
SO- from 210-J in the proper proportion for feeding the
reactor-regenerator system and passed through the feed
preheater, 403-C, to raise the temperature above the dew
point of the sulfur that is formed in the primary reactor.
The principal function of the catalytic reduction system
is to achieve maximum utilization of the reductant while
producing both sulfur and H S such that the proper ratio
of H S/SO- of 2:1 is realized for the subsequent Claus
reaction. The preheated gas mixture enters the catalytic
reduction system through a four-way flow reversing valve
and is further heated as it flows upward through a packed
bed heat regenerator, 401-DB. The gas stream then flows
downward through the reduction reactor, 402-D. The temp-
erature of the gas entering the reduction reactor is con-
trolled by bypassing a quantity of cold gas around the
upflow regenerator.
Upon leaving the reactor, the main gas flow passes down-
ward through a second heat regenerator, 401-DA, giving up its
heat to the packing in that vessel before leaving the catalytic
reduction system through the flow reversing valve. A thermal
balance is maintained in the system by passing a minor flow
of the hot gases around the downflow regenerator and the flow
reversing valve and remixing with the main stream. The direction
of flow through the two heat regenerators is periodically
reversed to interchange their functions of heating the feed
gas and cooling the product gas.
The effluent gas from the reactor-regenerator system is further
cooled in the mixed gas cooler, 404-C. Some sulfur is condensed in
56
-------
this unit and it flows to the sulfur pit, 401-F. Low pressure
steam is generated on the shell side of this unit. A portion
of the gas from the mixed gas cooler then is used to heat the
feed gas in the feed preheater. Gas leaving the feed
preheater enters the 1st sulfur condenser, 405-C. Low
pressure steam is also generated on the shell side of this
unit. Some sulfur is condensed and it is sent to the sulfur
pit. Exit gas is then blended with hotter gas from the mixed
gas cooler to feed the 1st Claus reactor, 403-D. Here the
following exothermic reaction takes place:
3S
The gas is cooled in the 2nd sulfur condenser, 406-C, and
the liquid sulfur formed flows to the sulfur pit. Further
conversion to sulfur takes place in the 2nd Claus reactor
404-D. Sulfur is condensed in the 3rd sulfur condenser,
407-C, and flows to the sulfur pit. Low pressure steam is
also generated on the shell side of the 2nd and 3rd sulfur
condensers.
The gas stream then enters the tail gas mist eliminator,
401-G, for removal of entrained liquid droplets. Residual
H_S in the gas is oxidized to SO in the tail gas incinerator,
£, £
401-B. Air is supplied to this unit by the dilution air
blower, 403-J, and the combustion air blower, 404-J. The
incinerator outlet gas containing S02 is recycled to the
absorber in the scrubbing area to minimize SO emission
to the atmosphere.
Product sulfur is pumped from the sulfur pit to the sulfur
storage tank, 309-F, via the sulfur pit pumps, 402-J.
57
-------
B. Coal Cleaning Process (See Appendix D)
The process description which follows is based on a coal
preparation plant with a capacity of 600 t/h of raw
coal feed, operating two shifts/day for 220-260 days/yr.
The total coal processed at such a plant would be 2.112
MMTons/yr. The site for the plant will require about
25 acres; an additional 75 acres should be acquired ad-
jacent to the plant for refuse disposal. The utilities
and manpower requirements for such a plant are itemized
below:
Electric Power
Preparation plant
Materials handling and storage
Unloading and loading
Total
Manpower Requirements
Preparation plant 25 men
Refuse handling 3 men
Intermediate storage & handling 8 men
Make-up water requirements 200 GPM
Coal is received at the preparation plant in the raw coal re-
ceiving bin, 101-F. It is transferred from there to the 1500
raw coal silo, 102-F, via a conveyor. The plant feed conveyor
transports the raw coal to the preparation plant where it is
first screened in the raw coal screen, 101-G,and the pre-wet
screen, 102-G. This operation serves to separate the coarse
coal particles (5" x 1/4") which make up about 70% of the coal
feed, from the fine coal particles (1/4" x 0).
The slurry containing the fine coal particles passes first to
a stationary screen (sieve bend screen, 103-G), and then to a
desliming screen, 104-G. Slurry passing through this screen
58
-------
flows first to classifying cyclones , 116-G. The underflow
from these cyclones (28M x 200M) flows to froth cells, 117-G.
The overflow from the classifying cyclones (200 M x 0) flows to
the thickener, 102-L. Coal (1/4" x 28M) from the desliming
screen, flows to the pulp sump, 103-F, where it is mixed with
concentrated magnetite. This stream is then directed to the
heavy media cyclone, 105-G, where gravity separation taxes
place. The heavy media slurry containing pyrites flows to the
refuse drain and rinse screen, 106-G. Refuse is screened off
here and sent to the refuse bin, 106-F, and the heavy media
slurry flows through the screen to the heavy media sump, 104-F.
It is picked up from the sump by the heavy media pumps, 101-J,
and transferred back to the pulp sump, 103-F.
The overflow from the heavy media cyclone containing small
coal particles (1/4" x 28M) flows over a second sieve bend
screen, 107-G, and then to the clean coal drain and rinse
screen, 108-G. Dilute magnetite flows through this screen
and combined with the rinse underflow from the refuse screen,
106-G, flows to the magnetic separator, 109-G, which concen-
trates the magnetite and returns it to the heavy media sump.
Clarified water separated here is returned to the screen
sprays. Fine coal (1/4" x 28M) from 108-G then is trans-
ferred to the centrifugal dryer, 110-G. This unit separates
the fine coal (1/4" x 28M), which is transferred to the clean
coal silo, from a slurry. The slurry is sent to the froth
cells, 117-G.
Coarse coal (5" x 1/4") which was screened off in the front
end of the process is transferred to the heavy media washer,
111-G, where a gravimetric separation is made in a magnetite
bath. Refuse is separated at this point and transferred to the
refuse drain and rinse screen, 112-G. The rejected material
(5" x 1/4") is screened off at this point and transferred to
the refuse bin, 106-F, along with the remainder of the refuse.
Concentrated magnetite flowing through this screen flows back
59
-------
to the heavy media sump, 105-F, while dilute magnetite flows
to the magnetic separator, 115-G.
Coal from the heavy media washer flows to the clean coal drain
and rinse screen, 113-G. Coarse coal (5" x 1-1/2") overrides
this screen and is sent to the crusher, 101-L. Coal from the
crusher (1-1/2" x 0) is then transferred to the clean coal silo,
107-F. Coal overriding the second deck (1-1/2" x 1/4") is then
transferred to a centrifugal dryer, 114-G. Slurry is separated
from the coal at this point and transferred to the froth cells,
117-G. The clean coal from the centrifugal dryer (1-1/2" x 1/4")
then joins coal leaving the crusher to be transferred to clean
coal storage.
Concentrated magnetite from the clean coal drain and rinse
screen flows to the heavy media sump, 105-F. From here it
is picked up by 102-J and transferred back to the heavy media
washer. Dilute magnetite from the clean coal drain and rinse
screen flows through the screens to the magnetic separator,
115-G. Concentrated magnetite from this unit flows to the
heavy media sump and clarified water is returned to the
screen sprays.
From the froth cells, 117-G, small coal particles (28M x 0)
are sent to the clean coal filter, 118-G. Filtered coal
is then transferred to clean coal storage. The filter over-
flow is pumped to the screen sprays. The static thickener,
102-L, receives the refuse slurry from the froth cells. A
further feed to the thickener is a slurry stream which comes as
the overflow from the classifying cyclones, 116-G. Refuse
from the thickener is transferred to the refuse filter, 119-G.
Filter cake from this unit (28M x 0) then joins the remainder
of the plant refuse. Water from this filter is returned to
the screen sprays. Clarified water from the thickener is
sent to 108-F from where it is returned to screen sprays.
60
-------
Make-up water for the process is sent to the make-up water
tank, 108-F. Water from the thickener also flows to 108-F.
Water is pumped from this vessel to the screens to be used as
screen spray.
A supplemental system which can be used in the coal pre-
paration plant includes a thermal dryer, 101-B. This unit
receives as feed, coal (1/4" x 28M) from the centrifugal
dryer, 110-G and from the clean coal filter (28M x 0). It
reduces the water content of the fine coal (1/4" x 0) to
the desired surface moisture level. Dried coal from the
thermal dryer is then transferred to the clean coal silo.
61
-------
V. DESCRIPTIONS OF POWER PLANTS IN IOWA
A. Des Moines Plant (See Fig. 11, 23)
The Des Moines Plant is a coal, oil and gas fired steam
electric power plant owned by Iowa Power & Light Company.
It has a generating capacity of 325 raw, the second largest
in the state. It is located on the north bank of the Des Moines
River in Des Moines, Iowa.
The plant is situated just north of a bend in the Des Moines
River on a site of approximately 60 acres. The plant
site is bound on the south, the southwest and the southeast
sides by the Des Moines River. An oil storage tank farm
lies north of the plant past the coal pile. The boilers
are enclosed in a building which runs in a north-south
direction. West of the power house is a large cooling
tower running in a northwest to southeast direction. The
cooling tower is situated above its basin. A 46 kv substation
is located due east of Boilers 7 and 8 and a parking lot is
located due east of Roiler 11. Highway 46 runs in a north-
south direction dividing the plant property. It crosses the
river just east of the 46 kv substation. Just east of High-
way 46 is a large 69 kv electrical switchyard and east of
it is an even larger 161 kv electrical substation. North
of these electrical facilities is a large ash disposal pond.
The pond is approximately 900' wide and 1000' long. Rail-
road tracks enter the boiler area from the northwest and
from the northeast.
Coal is received at the Des Moines Power Plant by rail and
by truck from a number of different sources. Some western
coal is burned at this plant. Total coal used in 1972 was
524,000 tons. The average properties of this coal on an
as received basis are as follows:
62
-------
HHV : 9400 Btu/lb
%S : 4.1
%Ash : 15.2
%Moisture : 16.9
Coal is stored in a large pile located north to northwest
of the power plant.
The Des Moines plant has 6 boilers and 7 generators which
range in capacity from about 30 to 110 mw. Boilers 6, 7,
8 and 9 supply steam to five turbines through a common
steam header. Boilers 10 and 11 each have their own turbine
and generator. The average load factor for the Des Moines
power plant in 1972 was 58.5%. Boiler 6 uses gas exclusively.
It is a front firing boiler. The standby fuel for this unit
is No. 2 fuel oil. Boilers 7, 9 and 9 are pulverized coal,
tangential-fired units. Boilers 10 and 11 are pulverized
coal, front-fired units. Units 7 and 8 are tied together
to a common stack 250' high. Units 9, 10, and 11 each has
its own stack. These stacks are also 250* high.
Boilers 7, 8 and 9 are served by cyclones for removal
of fly ash. Estimated efficiency of these units is 65%.
Boilers 10 and 11 are presently served by multiple cyclones
with a design efficiency of 75%. These units are scheduled
to be removed in mid 1974 for the installation of new
electrostatic precipitators. The new ESP's "are designed
to remove 99.3% of the fly ash.
63
-------
B. The Pella Plant (See Fig. 33)
The Pella Plant, located in the small town of Pella
(about 40 miles southeast of Des Moines), is owned and
operated by the Pella Municipal Power and Light Company.
The area is sparsely populated, primarily rural, and
lightly industrialized.
Rated at 44 mw, the plant has operated largely on Iowa
coals from nearby mines; but some consideration is being
given to cleaner "foreign" coals, particularly from the
West. In 1972, the 62,000 tons burned came from mines in
Marion and Mahaska counties and were trucked very short
distances. There are rail facilities nearby as well.
The coal burned in 1972 had the following average proper-
ties:
HHV : 8800 Btu/lb
%S : 6.6
%Ash : 17.5
%Moisture : 14.8
There are six boilers in the plant, and coal, oil or
natural gas are the design fuels. However, only two of
the boilers, the number 6 and 7 units, are used for base-
load operation; the others are either stanby units or are
being phased out. The two generators are connected by a
common header. The two base-load boilers are fairly new,
one commissioned in 1964 and the other 1972. The average
load factor in 1972 was 20.3%. The boilers are dry
bottom, spreader-stoker fired units.
64
-------
A new stack serves both boilers, which feed flue gas
through common breeching to a new electrostatic precipi-
tator designed for 95% efficiency. The stack is roof-
mounted and stands 250 feet above grade.
The site is triangular in shape, bounded on the north and
east legs by city streets and on the hypotenuse by a rail
spur. Space is severely limited on-site because of the
in-town location. The total area occupied by the plant
is only about 3 acres. The substation is small and
located west of the main building. Space for coal storage
is severely limited and is situated near the cooling
towers east of the building and south as well. There is
no ash pond, ash being stored in a silo for periodic haul-
age by truck to land fill sites.
65
-------
C. Iowa State University Steam and Power Plant (See Fig. 34)
This plant is located on the campus of Iowa State
University in the town of Ames, in central Iowa.
Although the installed generating capacity is only
25 mw, the plant consumes considerable more energy
than would be expected since it provides steam for
heating campus-wide.
Two of the existing five units are coal-fired, and the
other three are designed for coal and gas. A new boiler
which is slated for commissioning in mid-1975 will re-
place the old number 4 unit and will be designed to use
coal, oil or gas. In past years this plant made exten-
sive use of Iowa coals, but due to the impending sulfur-
control regulations, it was expected that 1974 would
see exclusively Illinois coal in use. In 1972 some
95,000 tons of coal was received by train from Iowa,
Illinois and Oklahoma mines. This coal had the following
properties:
HHV : 11,300 Btu/lb
%S : 4.0
%Ash : 11.5
%Moisture : 9.7
Capacity factors are high in the ISU plant, averaging
some 80-90% in 1972. All of the boilers are relatively
alike in size, consuming about 10-14 t/h of coal; they
were added piecemeal at about 8 year intervals as demand
increased. They were placed in service from 1946 to 1974.
Presently there are no electrostatic precipitator installa-
tions in place or planned, but efficient multiple cyclones
66
-------
(92%) are anticipated to be installed by mid-1974.
Ash is trucked out to landfill sites; there is no ash
pond, and temporary ash storage is handled in a silo.
Space is severely limited at the site since it is on
the campus proper. Because of the presence of nearby
academic and administrative buildings there is little
possibility of expansion.
Coal storage is east of the main building and occupies
only a few acres. The rail siding and unloading facili-
ties skirt the north boundary, and the southern side is
confined by Wallace Road. The area is somewhat hilly.
There are buildings nearby in every direction. Because
of the nature of the plant, there is no large switch
yard and substation. Northwest of the plant.are water
treating and storage facilities and the cooling towers.
An old stack at the southern edge of the building is
to be removed and a new one 190 feet high will serve
two of the 5 units (Units 5 and 6) while the other
three (UrJts 1/2, and 3) will be served by a 160-foot
high stack.
67
-------
D. Maynard Plant (See Fig. 12, 24)
The Maynard Plant is coal, oil, and gas fired steam electric
plant owned by Iowa Public Service Company. It has a
generating capacity of 107 mw and it is located on the
north bank of the Cedar River in Waterloo, Iowa.
The plant is located on a fairly congested site. It is
bound on the south and west sides by the Cedar River, on
the north side by Lafayette Street and on the east side by
another street. The area of the property south of Lafayette
Street is about 7 acres. The ash pond, coal yard, and
fuel oil storage tanks are located across Lafayette Street
northwest of the boiler area. Due north across Lafayette
Street is the City Water Works and adjacent to it is an
industrial area. A residential area lies east of the
plant across the city street. Several railroad tracks
approach the boiler plant from the north side. A 69 kv
substation and a 34.5 kv substation are situated northwest
of the boilers.
Coal is received by rail from Illinois. In 1972, the
plant used 82,000 tons of coal having the following
properties as received:
HHV : 10,900 Btu/lb
%S : 2.5
%Ash : 11.0
%Moisture : 12.0
The Maynard Plant has 5 boilers and 4 generators ranging
in capacity from 12 to 58 mw. Boiler 14 is base loaded
and boilers 9, 10, 11, and 12 cycle in capacity. All
boilers can burn coal and gas and, in addition, Unit 12
68
-------
can also burn fuel oil. Average plant load factor in
1972 was 40.0%. The boilers were placed in service from
1937 to 1958. Units 9 and 14 are pulverized coal fired
and Units 10 and 11 are stoker fired. Units 9, 10, and
12 are served by a common stack 220 feet high. Unit 11
has its own stack which is 220 feet high and Unit 14 also
has its own stack which is 250 feet high.
Fly ash is removed from the flue gas from Boilers 9 and
11 by Western Multiclones. Boiler 10 has a Pratt-Daniel
Thermix Tubular cyclone. Boiler 12 has a mechanical pre-
cipitator^ Boiler 14 is served by a Joy electrostatic
precipitator with a design efficiency of 99%.
69
-------
E. Muscatine Plant (See Fig. 13, 25)
The Muscatine Plant is a coal fired steam electric power
plant owned by the Muscatine Municipal Electric Plant.
It has a total installed generating capacity of 117 mw.
The plant is located on the west bank of the Mississippi
River in a rural area near Muscatine, Iowa.
The plant has 4 boilers (No. 5 through No. 8) in a row
facing the river with Unit 5 on the north and Unit 8
on the south. Maple Grove Road runs north-south in the
narrow space between the boiler house and the Mississippi
River. A 69 kv electrical substation is situated due
west of Unit 8 and another substation is located west of
Units 5,6 and 7. The older portion of the power plant
located on the north side of Unit 5 is to be dismantled.
Railroad tracks approach from both the west and the south
making a large loop through the southwest quarter of the
plant. The plant area east of the railroad tracks to
Maple Grove Road occupies about 13 acres. Some relatively
open farm land lies west of the plant.
Coal is stored in a large pile about 400' wide and 600'
long which is located south of Unit 8. The plant used
251,000 tons of coal in 1972. This coal was shipped from
Illinois and had the following average properties as
received:
HHV : 10,900 Btu/lb
%S : 3.0
%Ash : 10.2
%Moisture : 16.4
Coal is received at the Muscatine Station by rail and by
barge. The barge dock and the unloading facilities are
70
-------
located out over the water southeast of the plant,
some 160 feet from the river bank.
The four boilers of the plant are associated with four
generators ranging in capacity from 7.5 to 84 mw. Unit
5 is the smallest and is used for standby. Unit 6 is
used for peaking and Units 7 and 8 are base loaded.
Unit 8 rated at 84 mw is by far the largest. Average
load factor in 1972 was 57.9%. Units 5,6, and 7 are
spreader stoker-fired and Unit 8 is cyclone-fired. The
boilers were placed in service from 1941 to 1969 and
have an expected remaining life of 7-35 years. Units
5,6, and 7 will be tied together and served by one new
stack 220 feet high. Unit 8 is served by its own stack
320 feet high.
Units 5 and 6 are to be served by new mechanical dust
collectors rated at 80% efficiency which are to be
placed in service in May, 1975. Unit 7 is presently
served by a mechanical dust collector rated at 80%
efficiency. In addition, a new ESP is to be installed
in May, 1975 to serve Unit 7. This will be a cold side
ESP rated at 90% efficiency. Unit 8 presently has a
Research-Cottrell cold side ESP rated at 95% efficiency.
71
-------
F. The Fair Station (See Fig. 35)
The Fair Station is located in the small town of Montpelier
in southeastern Iowa; it is a Mississippi River plant with
a generating capacity of 63 mw. The area is rural with light
population and industrial development. The plant is owned
by the Eastern Iowa Light and Power Cooperative of Wilton
Junction, Iowa.
There are two boilers, placed in service in 1960 and 1967,
each designed to burn coal or natural gas. The two gen-
erators have capacities of 25 and 41 mw.* There are two
stacks, each roof mounted 164 feet above grade. To date
the only ash collection equipment consists of multiple
cyclones designed for 85% efficiency but electrostatic
precipitators are planned for early 1975.
The approximate coal consumption in 1972 was 81,000 tons.
This coal was delivered to the plant by barge following a
rail leg from Illinois. Rail unloading facilities are
also available at the plant near the river dock. Coal used
in 1972 had the following average properties:
HHV : 10,900 Btu/lb
%S : 3.3
%Ash : 9.2
%Moisture : 11.3
*It is common to find plants in which name plate and
100% load ratings are not identical.
72
-------
Space for future expansion is not a serious problem at
the Fair Station site. Some room exists to the west of
the main building and north of the building near the
substation.
The coal storage pile occupies some 6.5 acres (440'x640')
due east of the main plant and north of the dock. Two ash
ponds are located at the opposite (west) end of the property.
The larger of the two is about 2.5 acres in area while the
smaller is about 220'x280' (1.5 acres). The major rail line
runs east and west along the north boundary and parallel to
State Highway 22. The river bounds the south property line.
The total plant site covers about 28 acres.
73
-------
G. The Riverside Plant (See Fig. 14, 26)
The Riverside Plant is located on the Mississippi River
in the city of Bettendorf, Iowa, and is owned by Iowa-
Illinois Gas and Electric Company. Generating capacity is
222 mw. The area is heavily populated, and industrial
development is very heavy.
Design fuels are coal and natural gas. There are 5 boilers
and 5 generators ranging in size from 16 to 140 mw. The
units were placed in service from 1937 to 1961. Boilers
5-8 are pulverized coal, front-fired units and Boiler 9 is
a pulverized coal, tangential-fired unit. In 1972 the
average load factor for the plant was 66.2%. All of the
boilers are enclosed and are served by individual electro-
static precipitator units rated at 99% efficiency. One
346' high stack serves the newest three boilers (7,8, and 9),
and the two oldest ones (5 and 6) have their own stacks
(each 144' high).
The plant grounds are rather crowded with equipment and
auxiliary facilities. Coal storage and handling and ash
storage areas are south of the plant proper; to the north
are more coal facilities and storage. West of the building
are parking areas, substations, rail facilities, water tanks,
gas turbine houses and other facilities. The river confines
the east property line.
Coal unloading facilities appear to be exclusively rail,
although the plant is on the river. In 1972 all the coal
used, some 472,000 tons, was brought in by rail from Illinois.
This coal had the following average properties:
74
-------
HHV : 10,400 Btu/lb
%S : 2.6
%Ash : 8.7
%Moisture : 16.8
The only availabe space on the property appears to be
north of the main building and close to the river.
75
-------
H. Burlington Plant (See Fig. 15, 27)
The Burlington Plant is a coal fired steam electric power
plant owned by Iowa-Southern Utilities Co. It has a
total installed generating capacity of 212 mw. The plant
is located on the west bank of the Mississippi River in
Burlington, Iowa which is in the southeast corner of the
state.
The plant has a single boiler with the stack being located
east toward the river and the turbine-generator room
being located west. The plant is situated on a fairly
large track of land (about 120 acres) which is bound on
the east by the Mississippi River and on the northwest
by the CB & Q Railroad. An old ash disposal basin (approx-
imately 500' x 800') is located due south of the plant.
A large new ash basin is located west of the coal pile and
northwest of the plant. Located due west of the turbine-
generator room is the main electrical substation. Rail-
road tracks parallel the river and enter the plant area
from the north.
Coal is stored in a large pile having dimensions of about
450 feet x 450 feet. The coal pile is located north of
the plant and a conveyor runs from the crusher building
some 450 feet to the silo bay of the boiler. The plant
used 544,000 tons of coal in 1972. It was shipped by
rail from Illinois and had the following properties:
HHV : 10,100 Btu/lb
%S : 2.6
%Ash : 8.2
%Moisture : 20.5
76
-------
The single boiler and generator are rated at 212 mw.
The unit was built in 1968 and has a remaining life of
about 25 years. Load factor in 1972 was 59.2%. The unit
is designed for pulverized coal, tangential firing. It
is served by a single stack 306' tall.
Fly ash is removed from the flue gas by a UOP electrostatic
precipitator located on the cold side. Tested efficiency
of the unit at start-up was 98.5%.
77
-------
I. Dubuque Plant (See Fig. 36)
The Dubuque Plant, owned by Interstate Power Company,
is located on the Mississippi River in metropolitan
Dubuque. Generating capacity is 91 mw including all
units and 74 mw if the two oldest boilers are excluded.
The surrounding area is heavily populated and very
industrialized. The plant occupies an area of about
12-15 acres.
There are 5 boilers; design fuels are coal, oil and
natural gas. The boilers range in design coal consump-
tion from 8.7 to 25.2 t/h; load factors, from 2 (for
standby units) to 53.5; generating capacity, with 4
generators, 10.0 to 37.5 mw; commissioning dates, 1926
to 1959. Two oldest boilers were not fired at all in
1973. Average plant load factor in 1972 was 54.3%
(based on a generating capacity of 74 mw).
There will be 2 stacks, both 106 feet above grade.
Presently there is only one electrostatic precipitator
installed, but two other (newer) boilers will each have
ESP's by the end of 1974. All ESP's are cold side units
with design efficiencies of 99%.
Coal may be delivered either by barge or by train and is
stored in a yard southeast of the plant. In 1972 all
of the coal used (about 121,000 T) was supplied by barge
from Illinois. This coal had the following average proper-
ties:
HHV : 11,300 Btu/lb
%S : 3.2
%Ash : 10.9
%Moisture : 10.3
78
-------
Space is rather limited at this site due to its in-city
location. Miscellaneous city facilities and commercial
interests line the plant property on three sides, and
the river confines the east border. The only available
room for expansion appears to be south and northeast
of the main building. The precipitators and stacks are
south of the building, and a rail spur passes underneath
through to the river dock unloading facilities. The sub-
stations and poleyard are located to the north. One city
street (E. 8th St.) passes partway through the plant area.
The area to the northeast has power cables and poles in
it. There is no ash pond on-site; ash is trucked away
to landfill sites.
79
-------
J. The Lansing Plant (See Fig. 37)
The Lansing Plant, with 3 coal-fired boilers rated at
64 mw total generating capacity, is owned by Interstate
Power Company (of Dubuque). It is a Mississippi River
plant serving Lansing, in northeastern Iowa and environs.
The area is lightly populated, primarily rural, and light-
ly industrialized.
The boilers are designed for coal consumption of 7.4 to
18.5 t/h and are rated at 15 to 37.5 mw. They were
commissioned in 1948 to 1957 and operated ,at an average
load factor of 47.4% in 1972. Two stacks each 151 feet
above grade, serve them.
Electrostatic precipitators will be installed on all
three units before the end of 1974. The ESP's will be
cold side units with design efficiencies of 99%.
Coal may be delivered either by rail or by barge. In
1972 the 154,000 tons of coal used at Lansing was del-
ivered by barge from Illinois mines. The average prop-
erties of this fuel on an as received basis were the
following:
HHV : 11,200 Btu/lb
%S : 3.0
%Ash : 10.5
%Moisture : 11.1
Future plans call for a fourth boiler, generator and
precipitator system (and presumably another stack, as
well) which will probably be commissioned in 1977. More
immediately, changes will be made in the coal unloading
and water treatment facilities.
80
-------
Space is not a critical problem at this plant site;
expansion space for the new unit is located directly
north of the main building. A large open area west of
the substation and switch yard, which lies west of the
plant proper, is presently set aside for coal storage
for the new unit. Also there is a small space directly
southeast of the building, as well as a larger space
across the rail tracks in the same direction. Addi-
tional coal storage is located farther to the west.
The river curves around the north and east sides of the
site. A creek runs south and east of the plant and
proposed coal yard.
81
-------
K. The Kapp Plant (See Fig. 16, 28)
The M. L. Kapp Plant is owned by the Interstate Power
Company of Dubuque and is located on the west bank of
the Mississippi River near the small town of Clinton,
Iowa. Installed generating capacity is 237 raw. The area
is generally rural; industrial development in the general
vicinity is moderate to heavy.
The Kapp Plant has 2 coal-fired boilers, commissioned in
1947 and 1967, respectively, and 2 generators. Unit 1
is rated at 19 mw and is a pulverized coal, front-fired unit.
Unit 2 is rated at 218 mw and is a pulverized coal, tangen-
tial fired unit. Average load factor for the plant in 1972
was 59.8%. Both boilers are wet-bottom units and are
enclosed in the main building; both are served by separate
electrostatic precipitators and stacks. (The ESP for Unit 1
will be on steam in early 1975). The stacks are located
south of the building and are 210 and 245 feet tall.
The area occupied by the plant (excluding the ash pond)
is about 35 acres. High-voltage switch gear is located
at the northeast wall of the building; the power sub-
stations are located to the northwest on the other side
of the rail spur. An ash storage pond (approximately 50
acres) is located to the west of the substations and near
U.S. Highway 67. Ash is sluiced either to this pond or to
an emergency settling basin north of the plant via a 10-inch
sluice pipeline. Open space exists to the immediate west
of the building, where a third unit was once planned; evi-
dently this plan was subsequently abandoned,and the space
is presently used for parking, storage and construction.
Other than this, the only unused space inside the property
82
-------
line is south of the building, but this space is limited
by a railroad right-of-way, a water treatment plant and
one of the stacks. There is little available space nearby
outside the property line. The Mississippi River bounds
the east side; a city sewage disposal plant is located
north of the plant on the other side of a creek skirting
the north property line. The creek curves around the west
side line, leaving little space between the property line
and substations. To the south and southwest are DuPont
facilities and ponds.
Coal for the plant was supplied (1972) from three Illinois
mines by barge. Rail unloading facilities are also present.
The coal yard is east of the building. Design coal con-
sumption (100% rating) totals 103 t/h the plant used
575,000 tons of coal in 1972 having the following average
properties on an as received basis:
HHV : 11,000 Btu/lb
%S : 3.1
%Ash : 11.0
%Moisture : 11.8
83
-------
L. Prairie Creek Plant (See Fig. 17, 29)
The Prairie Creek Plant is a coal, oil and gas fired steam
electric power plant. It has an installed generating
capacity of 245 mw. Units 1, 2, and 3 are rated at 96 mw
and are owned by Central Iowa Cooperative. Unit 4 rated
at 149 mw is owned by Iowa Electric Light & Power Company.
The plant is located on the west bank of the Cedar River
outside of Cedar Rapids, Iowa in a fairly rural area.
The plant site is a long narrow strip of land of about
50 acres in area extending westward from the Cedar River.
The property is bound on the north by the Chicago and
Northwestern Railroad and it is bound on the east by a
road. An open pasture lies to the south of the plant.
A 115 kv electrical substation is situated north of the
boilers. Some water treating buildings and offices lie
northwest of Unit 4. A number of railroad tracks run
through the property in an east-west direction. The ash
disposal basin is located at the west end of the property.
A parking lot is situated on the east side of the power
house.
Coal is stored in a large elongated pile (about 300' wide
x 2000" feet long) located south of the boilers. The plant used
497,000 tons of coal in 1972. The coal had the following
properties on an as received basis:
HHV : 10,500 Btu/lb
%S : 2.5
%Ash : 8.5
%Moisture : 16.9
Coal is received at the Prairie Creek station by rail. The
principle source of the coal is Illinois.
84
-------
The plant has four boilers and four generators ranging
in capacity from 23.5 to 149 mw. The boilers were placed
in service from 1960 to 1967. In 1972 the average load
factor for the plant was 53.5%. The boilers are arranged
in a row with number 1 boiler located on the east side
of the power house and number 4 boiler on the west side.
Units 1 and 2 are peak shaving, spreader-stoker fired boilers
Units 3 and 4 are base load, pulverized coal, front-fired
boilers. Units 1 and 2 share the same stack which is roof
mounted and 180' above grade. Unit 3 has its own stack
which is also roof mounted and 180' above grade. Unit
4 has its own stack which is located west of the power
house. It is mounted at grade and 200' high.
Units 1 and 2 have multiple cyclones for fly ash removal.
The design efficiency on these units is 85%. Unit 3
is served by an electrostatic precipitator designed for
9B~.6% removal of particulate matter. Unit 4 is served
by multiple cyclones designed for 80% particulate removal.
A new electrostatic precipitator is now being installed
on Unit 4. Scheduled completion date is October, 1974.
85
-------
M. 6th Street Station (See Fig. 38)
The 6th Street Station is a coal, oil and gas fired steam
electric plant owned by Iowa Electric Light & Power Company.
It has a generating capacity of 92 mw and is located in
downtown Cedar Rapids, Iowa. In addition to the other
fuels mentioned, the plant also burns considerable amounts
of furfural waste. A substantial portion of the steam
generated at the 6th Street Station is used for heating
purposes.
The plant is located in a very conjested area of approximately
five acres. The boilers are enclosed in a building which
is located at the south corner of the property. The plant
is bound on the northwest and south sides by railroad tracks
and on the north side by Cedar Lake. Water storage tanks,
chemical storage facilities and water treating equipment
occupy the space northeast of the power house. A 33 kv
electrical substation is located north of the plant. A
115 kv electrical substation lies northeast of the 33 kv
substation. Immediately south of the boiler area is a
small parking lot. West of the plant, across the railroad
tracks is a Quaker Oats plant. There is no coal pile at
this plant simply because there is no room for one. Coal
is unloaded from railroad cars to a hopper and is
then conveyed directly to the coal bunkers at the power
plant.
The plant burned 260,000 tons of coal in 1972. Average
properties of this coal on an as received basis are as
follows:
HHV : 10,300 Btu/lb
%S : 2.3
%Ash : 7.6
%Moisture : 20.0
86
-------
The plant has 10 boilers and 10 generators ranging in capacity
from 6 to 25 mw. The boilers were placed in service from
1937 to 1950. Average load factor for the plant in 1972
was 31.4%. All boilers are pulverized coal, front fired
units and all have the capability of also firing residual
oil. There are 5 stacks at the 6th Street Station, each
being 198' high. Boilers 1 and 2 are served by stack 1;
Boilers 3 and 4 by stack 2; Boilers 5 and 6 by stack 3;
Boilers 7 and 8 by stack 4; and Boilers 9 and 10 by stack
5.
Ply ash is removed from the flue gas from Boilers 1 and 2
by cylcones with a design efficiency of 47%. Four electro-
static precipitators serve the other eight boilers. The
design efficiency on the ESP's serving Boilers 3-4, 5-6, and
7-8 is 98%. The design efficiency on the ESP serving
Boilers 9-10 is 99.3%.
87
-------
N. Sutherland Plant (See Fig. 18, 30)
The Sutherland Plant is a coal fired stea'm electric power
plant owned by Iowa Electric Light and Power Company. It
has a total installed generating capacity of 157 mw.
The plant is located in a rural area near Marshalltown,
Iowa.
The plant is situated on a fairly large open site of
about 80 acres. The cooling tower for Unit 3 is located
about 400 feet due east of Unit 3 and the cooling tower
for Units 1 and 2 is located about another 300 feet due
east of the other cooling tower. An ash basin (8001 x 600')
is located east of the cooling tower for Units 1 and 2.
Coal is transported to the boilers by conveyors which enter
from the north side. Some oil storage tanks are located
in a tank field about 500-650 feet northwest of the boilers.
A parking lot is situated just south of the boilers. A
115 kv substation is located southwest of the boiler area.
There are some open areas due east as well as southeast
of the boilers.
Coal is stored in a large pile (about 300' x 1000') north-
east of the boilers. The plant used 199,000 tons of
coal in 1972. This coal had the following properties:
HHV : 10,100 Btu/Lb
%S : 2.8
%Ash : 11.7
%Moisture : 16.0
Coal is received at the Sutherland Station by rail.
The plant has three boilers and three generators ranging
in capacity from 37.5 to 81.6mw. The boiler houses are
88
-------
enclosed and the boilers are arranged in a row with Unit
1 to the west and Unit 3 to the east. The boilers were
placed in service from 1955 to 1961. In 1972 the average
load factor was 73.5%. Boilers 1 and 2 are pulverized coal,
front firing types and boiler 3 is cyclone firing type.
Each boiler is served by its own stack and each stack is
190 above gride.
The original installation had multicyclones on all three
units for fly ash removal. Design efficiency of the units
was 80%. Each boiler will have a new ESP installed for
final clean up by early 1975. The new ESP's for Units 1 and
2 will be mounted on a steel structure just north of the
boilers. The new ESP for Unit 3 will be mounted on the roof
of the building. All new ESP's will be downstream of the
air heaters (cold gas side).
89
-------
VI ESTIMATES FOR FLUE GAS SCRUBBING
A. Detailed Estimates for Wet Limestone Systems
1. Results
The capital investment required to install Wet Lime-
stone scrubbing systems on each of the eight selected
Iowa power plants are tabulated below:*
Gen Cap:
MW
325
107
117
222
212
237
245
157
Capital Total
Invest: Int. During Capital
$MM Const: $MM Inv: $MM
22.1
14.7
10.3
17.2
13.0
14.5
17.8
15.5
2.2
1.5
1.0
1.7
1.3
1.4
1.8
1.5
24.3
16.2
11.3
18.9
14.3
15.9
19.6
17.0
$/KW
74.60
151.10
96.90
85.00
67.40
67.00
80.10
108.30
Muscatine
Riverside
Burlington
Kapp
Prairie Creek
Sutherland
Total 1622 125.1 12.4 137.5 84.80 Avg,
These estimates assume that a thickener and small pond
(2 weeks storage) are provided for sludge disposal.
Sludge would have to be removed from the plant site
via truck, rail or barge. If a long term sludge pond
were provided the capital investment required would
increase. The extent of the increase would depend on
several factors:
- the number of years of sludge storage provided for
- the sulfur content of the coal feed
- the type of pond lining used and thickness of
the lining.
* Costs are on a January, 1974 basis.
90
-------
Detailed estimates for Wet Limestone scrubbing were
also prepared for the following smaller plants: Pella,
Iowa State University, Fair, Dubuque, and Lansing.
The average capital investment for these five plants
was $171.10/kw. No detailed estimate was prepared for
the Sixth Street Station due to the unusually crowded
conditions existing at the plant site. These six
plants were dismissed from consideration for stack
gas scrubbing due to their small size (and high unit
investment cost) and due to space limitations.
2. Procedure
The design proposed by the Tennessee Valley Authority
for their Widows Creek Unit 8 Wet Limestone Scrubbing
system was used. Some slight modifications were made
in both the limestone handling system and the scrubbing
system (14).
To evaluate the capital investment required for Wet
Limestone Scrubbing at 13 power plants containing
many boilers of different sizes, it was decided to
develop several different standard size scrubber modules.
It was found that eight standard scrubber modules would
be sufficient to adequately cover the range of boiler
sizes involved.* The largest scrubber module (Size I)
is capable of treating flue gas from a boiler generating
about 167-182 mw and the smallest scrubber module (Size VIII)
is capable of treating the flue gas from a boiler generating
about 28-30 mw. Vendor quotations were obtained for
the major equipment items in the largest (Size I)
scrubbing train. Costs for the smaller size trains
were pro-rated down from this cost.
* The number and size of the standard scrubber modules are
chosen to best match the flue gas flow from each power
plant.
91
-------
Prices of the major equpiment items in the limestone
handling and grinding system were also obtained from
vendor quotations. The equipment in this area includes
conveyors, pumps, motors, ball mills ani the grinding
building. Subcontract cost items in this area include
the limestone silos, thickener, slurry tank, effluent
tank, and unloading hopper. Prices for different
equipment sizes were obtained so that a cost curve
could be prepared for the limestone handling and
grinding system.
Using the drawings obtained from the power companies,
layout sketches were made showing the number, size,
location, and orientation of the scrubbing modules.
Also shown on the drawings were the limestone storage,
handling, and grinding facilities. In addition, major
revamp work needed to install the Wet Limestone Scrubbing
system at each plant was indicated on the drawings.
Process flow sheets for the limestone handling and
grinding system and for the scrubbing system were
prepared. Three different standard scrubber module
drawings were also prepared and layout dimensions
were provided for them. A tabulation of the eight
standard scrubber module sizes and capacities was
completed. Also a tabulation of standard piping
sizes for each different scrubber module was made.
The M. W. Kellogg Estimating Department was used to
prepare the detailed capital estimates for the 13
Iowa power plants. General information transmitted
to the Estimating Department included the following:
- cost of standard scrubber modules
- cost curve for limestone system
- standard piping sizes
- standard scrubber module drawings
92
-------
- isometric scrubber module sketch
- process flow sheets
- tabulation of standard scrubber module sizes
and capacities
Specific information turned over to the Estimating
Department for each plant included the following:
- power plant summary sheet showing number
of scrubbing trains required, the train size,
train type, additional duct work required (if
any) and pond size requirement
- a plot plan for the power plant showing the
location of the scrubbing trains, the location
of the limestone handling and grinding system,
and notes indicating extra work which must be
done at the power plant (such as relocation of
tanks, buildings, railroad tracks, fences,
miscellaneous equipment, etc.)
With this input information, the M. W. Kellogg Estimating
Department prepared capital estimates for each of
the 13 power plants. The estimates include major
equipment as well as site preparation, steel structures,
buildings, piping, electrical, instruments, insulation
and paint, subcontracts, construction costs, procurement,
engineering, central staff, sales tax, insurance, start
up cost, contractor overhead and profit, and construction
interest.*
* Due to the nature of the task, the overall accuracy of
the estimates is expected to be about 30-35% with the
probability of underrun being very small.
93
-------
B. Computerized Estimates
1. Wet Limestone Scrubbing Cost Model'
The M.W. Kellogg model for wet limestone scrubbing
was developed in a report entitled "Evaluation of
R & D Investment Alternatives for SO Air Pollution
J^
Control Processes." This report was performed
under EPA Contract 68-02-1308, Part I, Task 7(3, pp. 83-98).
The model was programmed on the Wang 720 computer
to facilitate evaluation of different process
variables. For a description of the process, refer
to Section IV in this report. The process flow sheet
and equipment list are included in the Appendix
of this report. Equations used in this model are
listed in the following sections:
a. General Equations
(1) SF = (MW) (BtuAWH) (Wt.FR.SULF) M LB/HR
(BtU/LB)
(2) SO, Emission = (2) (SF) (106) LB S02/MMBtu
(No Control) (MW) (Btu/KWH)
(3) S02 Emission = d-SO2 Removal)/SO_ Emission\LB S02
(After Scr) \No Control /MMBtu
(4) Annual Power = (MW) (8.76) (LF) MMKWH/YR
Generated
(5) RB = 1 +
(6) GB = £W§ (MW) (0.00034196) MACFM/Boiler
Note: If GB is given, the program uses it.
94
-------
(7) TB = GB/550 NO. Scr. Trains/Boiler
(Note: If TB is fraction or 1, use 1 train;
If TB is > 1, use next larger integer number)
(8) GT = GB/TB
(9) GP = £GB
BOILER GEN. CAPACITY;
<50
50-100
101-200
201-500
>500
New
b. Capital Cost Equations
NA
MACFM/Train
MACFM/Plant
3.5
3.0
2.5
2.25
2.0
1.0
r
(1) EC = !>~ (TB-RB) 1041 (GT/550)0'5 + 408 (GT/550)
n=l L
+ 238 RP (GP/3,300)0'5 + 201 (SF/28)0'5
0'9
(2) ES = 1680 (SF/28)
P = 5,000
0.9
$M
\0.5
ISOf^l (l-ls) 5M
W
(4) L = 0.39 (EC) + 0.18 (ES)
(5) M = 0.82 (EC) + 0.09 (ES)
,6
(6) T = 170
'SP\°-'
28 j
(1-IS) (If required)
$M
$M
(7) BARC = 1.15 (EC + ES + M) + [P + 1.43 (L)]F + T
(If required) $M
95
-------
(8) TPI = 1.12 (1.0 + CONTIN) BARC
$M
(9) TCR - (1.03 + CONST INT) TPI + 0.8 TO-CO
(1+P) +0.4 ANR
(10) $/KW
TCR
MW
(11) $/MMBtU/H
TCR (10°)
MW (BtU/KWH)
c. Operating Cost Equations
(1) AL = 600 CL-LF (SF/28)
(2) AA = 0.43 CA (SF/28)
(3) AW = 230 CW-LF [(GP/3,300) + (SF/28)]
(4) AF = 1,800 CF-LF (GP/3,300)
(5) AE = CE-LF [213 (GP/3,300) + 35 (SF/28)]
(6) ASL = 2210 (CSL) (LF) (SF/28) (1-Is)
(7) ANR
ASL
(8) TAG 0.237 TPI +2.1 TO-CO (1+F) + 1.04 ANR
(9) Mills/KWH =
TAG
(10) $/MMBtu
MM KWH/YR
Mills/KWH (105)
BtU/KWH
$M
$/KW
$/MMBtu/HR
d.
$M/YR
$M/YR
$M/YR
$M/YR
$M/YR
$M/YR
$M/YR
$M/YR
Mills/KWH
«/MMBtu
Economic Factors Used for the Wet Limestone Model
Fraction S02 Removal 0.90
Purchased price of limestone ($/T) 4.00
Purchased price of ammonia ($/T) 50.00
Purchased price of water ($/M GAL) 0.20
Purchased price of fuel oil ($/MMBtu) 0.80
96
-------
Purchased price of electricity (Mills/KWH) 8.00
Average hourly wages per Gulf Coast ($/HR) 7.00
Total number of operators 8.00
Construction interest (Fraction) 0.10
Contingency (Fraction) 0.00
Location factor 1.52
Load factor (Fraction) 0.70
Sludge disposal cost ($/T) 1.50
e. Nomenclature - General and Fixed Capital Investment
GP Total flue gas from plant MACFM
GT Maximum flow of gas into each venturi
(Maximum value of GT = 550) MACFM
GB Total flue gas from one boiler MACFM
NA Number of boilers/plant
TB Number of scrubbing trains/boiler
SF Maximum flow of sulfur into the control
unit M LB/HR
LF Load factor of the power station
E Major equipment cost
(Material and subcontract) $M
M Other material costs (piping,
instruments, electrical, civil etc.) $M
L Direct field labor costs $M
C, S Letters follows E, M'and L
C refers to chemical process type
equipment
S refers to solid handling equipment
P The total cost of the settling pond
(Material and total labor)
T Thickener cost if required (subcontract) $M
RB The retrofit difficulty factor of a
boiler
RP The retrofit difficulty factor of all
scrubbing equipment which is not in
parallel trains. Assume to be equal to
the highest RB
F Location Factor
Is Sludge pond indicator (Is= 1 for large pond;
Is= o for small pond and thickener)
97
-------
CONST INT Construction Interest
CONTIN Contingency
BARC Bare cost of control unit
TPI Total plant investment
TCR Total capital required
Nomenclature - Operating Cost
$M
$M
$M
AL
AA
AW
AF
AE
ASL
ANR
CL
CA
CW
CF
CE
CSL
TO
CO
TAG
Total annual cost of limestone $M/YR
Total annual cost of ammonia $M/YR
Total annual cost of process water $M/YR
Total annual cost of fuel oil $M/YR
Total annual cost of electricity $M/YR
Total annual cost of sludge disposal $M/YR
Summation of annual costs of chemicals,
utilities, etc. $M/YR
The purchase price of limestone $/T
The purchase price of ammonia $/T
The purchase price of process water $/M GAL
The purchase price of fuel oil $/MM Btu
The purchase price of electricity Mills/KWH
Cost of sludge disposal $/T
Total number of operators
The direct cost of operating labor $/HR
Total annual production cost $M/YR
98
-------
Wellman-Lord/Allied Cost Model
The M.W. Kellogg model on stack gas scrubbing using
the Wellman-Lord/Allied process was also derived from
the report entitled "Evaluation of R & D Investment
Alternatives for SO^. Air Pollution Control Processes" (3 , pp. 110^129).
For a description of the process, refer to Section IV
in this report. The process flow sheets and equip-
ment lists are given in the Appendix of this report.
The equations used in the model which was also programmed
on the Wang 720 computer are given in the following sections:
a. General Equations
(1) SF = (MW) (BtU/KWH) (WT.FR.SULF) LB/HR
(BtU/LB)
(2) S02 Emission = (2) (SF) (106) LB SO2/MMBtu
(No Control) (MW) (BtU/KWH)
(3) S00 Emission = (1-S00 Removal) /SO_ Emission\ LB SO,
2, i I z 1 _ £
(After Scr.) \NO Control / MMBtu
(4) Annual Power = MW(8.76) (LF) MM KWH/YR
Generated
(5) RB = 1.0 + [, ^X . . RBASE - Ij
3'5 L
=&£ 1
\J\Wn /
(6) GB = (MW) (0.00034196) MACFM/Boiler
\J\Wn /
Note: If GB is given, the program uses it.
(7) TB = GB/550 No. Scr. Trains/Boiler
(Note: If TB is fraction or 1, use 1 train;
if TB is > 1, use next larger integer no.)
99
-------
(8) GT = GB/TB
(9) GP = IGB
The following table is used for
PLANT GEN. GAP: MW
b. Capital Cost Equations
NA
(1) EA
n = 1
[~
<50
50-100
101-200
201-500
>500
New
3.5
3.0
2.5
2.25
2.0
1.0
(TB.RB) 726 (GT/550)
0'5
MACFM/Train
MACFM/Plant
639 (GT/550)°'9Jn + 119 RP (GP/3300)0'5
+ N7 [l33 (S7/7)0'5 + 127 IF (S7/7)0'6]
$M
(2) ES =N7[209 (S7/7)005 + 618 (S7/7)0'6
+ 157 (S7/7)0'9] $M
(3) EP = N28 [525 (S28/28)0'5 + 380 (S28/28)0'6
+ 86 (S28/28}°-7+ 306 (S28/28)0'8
+ 519 (S28/28)°'9J $M
100
-------
(4) ER = 998 (SF/28)0'5 + 287 (SF/28)0'6
+ 683 (SF/28)0'9 $M
(5) M = 0.429 EA + 0.742 ES + 0.827 EP + 0.772 ER $M
(6) L = 0.224 EA + 0.310 ES + 0.433 EP + 0.623 ER $M
(7) BARC = 1.15 (E+M) + 1.43 (L) (F) $M
(8) TPI = 1.12 (1.0 + CONTIN) BARC $M
(9) TCR = (1.03 + CONST INT) TPI + 0.8 TO -CO (1+F)
+ 0.4 ANR $M
(10) $/KW = $/KW
(11) $/MMBtu/HR = R° $/MM Btu/HR
c. Operating Cost Equations
(1) AS = 28.2 CS-LF (SF/28) $M/YR
(2) AAO = 0.04 CAO-LF (SF/28) $M/YR
(3) AN = 1460 CN-LF (SF/28) $M/YR
(4) AFA = 1.24 CFA-LF-IF (GP/3300) $M/YR
(5) AE = [154 (GP/3300) + 79 (SF/28)] CE-LF $M/YR
(6) AH = 5430 CH-LF (SF/28) $M/YR
(7) ACW = [856 (GP/3300) + 19,900 (SF/28)] CCW-LF $M/YR
(8) AW = 64 (SF/28) CW-LF $M/YR
(9) AF = 1,800 (GP/3300) CF-LF $M/YR
(10) ASC = 95.4 (SF/28) VSC-LF $M/YR
(11) APS =37.3 (SF/28) VPS-LF $M/YR
(12) ANR = AS + AAO + AN + AFA + AE + AH + ACW
+ AW + AF + ASC + APS $M/YR
101
-------
(13) TAG = 0.237 TPI + 2.1.TO-CO (1+F) + 1.04 ANR $M/YR
TAP
(14) Mills/KWH = 5555^5 Mills/KWH
,15,
d. Values of Economic Factors
Fraction S0_ Removal 0.95
RB Max.
Purchased Price of Na2C03: CS ($/T) 40.00
Purchased Price of Anti-oxidant: CAO ($/T) 40.00
Purchased Price of Natural Gas: CN ($/MSCF) 0.50
Purchased Price of Filter Aid: CFA ($/T) 50.00
Purchased Price of Electricity: CE (Mills/KWH)8.00
Purchased Price of Steam: CH ($/MLB) 0.70
Purchased Price of Cooling Water: CCW ($/MGAL)0.02
Purchased Price of Water: CW ($/MGAL) 0.20
Purchased Price of Fuel Oil: CF ($/MMBtu) 0.80
Value of Sulfur Credit: VSC ($/LT) 10.00
Cost of Purge Solids Disposal: VPS ($/T) 1.50
Location Factor: F 1.52
Load Factor: LF (Fraction) 0.70
IF (If fly ash present, IF = 1.00) 1.00
Average Hourly Wages, Gulf Coast: CO ($/HR) 7.00
Total Number of Operators: TO 16.00
Construction Interest (Fraction) 0.10
Contingency (Fraction) 0.00
e. Nomenclature - General and Fixed Capital Investment
GP Total flue gas to control plant MACFM
GT Total flue gas to each absorber train
(maximum value of GT = 550) MACFM
GB Total flue gas from one boiler MACFM
NA Number of boilers per plant
TB Number of absorber trains per boiler
102
-------
SF
S7
S28
N7
N28
E
M
L
A,S,P,R
F
LF
IF
RB
RP
Total sulfur flow in flue gas to
control plant
Total sulfur flow in flue gas to
control unit per train of sulfur-
related equipment in absorber and S02
regeneration areas (maximum value of
S7 = 7) .
Total sulfur flow in flue gas to
control unit per equipment train
in the purge/make-up area (maximum
value of S28 = 28)
Number of trains of sulfur-related
equipment in the absorber and SO2
regeneration areas.
Number of equipment trains in the
purge/make-up area
Major equipment cost (direct material
and subcontracts)
Field Materials Costs
Field Labor Costs
Letters following E, M, L
A refers to absorber area
S refers to S02 regeneration area
P refers to purge/make-up area
R refers to S0_ reduction area
No letter following refers to total for
all areas
Location Factor
Load Factor of Power Plant
Particulate index (IF = 1 if par-
ticulates are present in flue gas.
IF = 0 if particulates are absent)
Retrofit difficulty factor of each
boiler
Retrofit difficulty factor of gas-
related equipment in the absorber area
which is not in parallel trains, i.e.,
the fuel oil system; assumed to be equal
to the highest RB.
M LB/HP
M LB/HR
M LB/HR
$M
$M
$M
CONST INT Construction interest
103
-------
CONTIN
BARC
TPI
TCR
Contingency
Bare cost of the control unit
Total Plant Investment
Total Capital Required
$M
$M
$M
Nomenclature - Operating Cost
AS
AAO
AN
AFA
AE
AH
ACW
AW
AF
ASC
APS
ANR
CS
CAO
CN
CFA
CE
CH
CCW
CW
CF
VSC
VPS
TO
CO
TAG
Annual cost of sodium carbonate
Annual cost of anti-oxidant
Annual cost of natural gas
Annual cost of filter aid
Annual cost of electric power
Annual cost of steam
Annual cost of cooling water
Annual cost of process water
Annual cost of fuel oil
Annual sulfur credit
Annual purge solids credit or debit
Summation of annual costs of chemicals,
util., etc.
Purchase price of sodium carbonate
Purchase price of anti-oxidant
Purchase price of natural gas
Purchase price of filter aid
Purchase (or transfer) price of
electricity
Purchase (or transfer) price of steam
Cost of cooling water
Cost of process water
Purchase price of fuel oil
Unit value of sulfur (negative if
credit)
Unit value of purge solids (negative
if credit)
Total number of operators
Unit cost of operating labor
Total annual production cost
$M/YR
$M/YR
$M/YR
§M/YR
$M/YR
$M/YR
$M/YR
$M/YR
$M/YR
$M/YR
$M/YR
$M/YR
$A
$/T
$/MSCF
$/T
Mills/KWH
$/M LB
$/M GAL
$/M GAL
$/MM Btu
$/LONG TON
$/T
$/HR
$M/YR
104
-------
C. Comparative Economics of Wet Limestone vs. Wellman-Lord/Allied
Processes for SO- Removal
1. General
The M.W. Kellogg estimating department prepared capital
estimates for wet limestone scrubbing for 13 power plants
in the state of Iowa. Out of these 8 were selected as
potential candidates for a scrubbing process. The others
were rejected due to either lack of space for installing the
equipment or due to the small size of the power plants. The
plants selected as potential sites for scrubbing facilities
are the following:
Des Moines Plant
Maynard Plant
Muscatine Plant
Riverside Plant
Burlington Plant
Kapp Plant
Prairie Creek Plant
Sutherland Plant
The estimating department capital cost estimates for these
plants ranged from 67.0 to 151.1 $/kw. The average for
the eight v?as $84.80/kw. The cost model for wet limestone
scrubbing using RBMAX = 1-0, predicted an average cost of
$62.30/kw. It was found that the model using RBMAX =1.7
and RDACE = 3.5, predicted an average capital investment
cost of $86.40/kw for the eight plants involved. This figure
is almost identical to the capital cost predicted by the
estimating department. Incremental capital investment re-
quired over that which would be required by a new plant is
$24.10/kw on the average for the eight plants.
The scrubbing train area required for the Wellman-Lord/
Allied process is identical to that required by the Wet
Limestone process for a scrubber capable of processing a
given quantity of gas. Also the space required for the
105
-------
regeneration, purge/make-up, and SO. reduction areas is
similar to that required in the Wet Limestone system for
limestone storage, handling and grinding. Therefore, the
assumption was made that the degree of difficulty in re-
trofitting either process would be the same. That is,
if one process would require additional duct work, relocat-
ion of buildings, coal piles, railroad tracks or other
miscellaneous expenses, the other process would require the
same.
Using the computer program for the Wellman-Lord/Allied
process, the capital investment required for the eight
plants (using RBMAV =1.0) ranged from 72.1 to 106.4 $/kw
MAX
with the average being 87.1 $/kw. Using the program with
= 1.7 and R _.c_ = 3.5 the computer predicted an
MAX
average cost of 109.8 $/kw. Therefore, the incremental in-
vestment for retrofitting the plants is 22.7 $/kw (almost
identical to that for the Wet Limestone system).
2. Economic Comparison of the Wet Limestone Process vs. the
Wellman-Lord/Allied Process
a. Basic Assumptions
Heat Rate = 11,000 Btu/KWH
HHV = 10,000 Btu/lb
TiD
= 1.7
= 3.5
F = 1.52
LF =0.70
CSL = 1.50/T
The heat rate of 11,000 Btu/kwh and HHV (of coal) of
10,000 Btu/lb were used as they represented the approx-
imate average values for the eight plants selected as
scrubbing candidates in the State of Iowa. As noted
106
-------
above, the RB of 1.7 and RfiASE of 3.5 are used to
calculate the increased cost of retrofitting stack gas
scrubbing systems into existing plants in Iowa. The
location factor (F) of 1.52 represents the ratio of
Iowa labor cost to Gulf Coast labor cost. The load
factor of 0.7 was chosen as a practical average power
plant load factor, although this may vary from plant
to plant and from area to area. The actual load factor
that a power plant will operate at in a future year is
difficult to predict because of the uncertainty of
the rate of population growth as well as that of indus-
trial growth in the area. The cost of sludge disposal
for the Wet Limestone process was assumed to be $1.50/T.
Other economic factors such as the prices of chemicals,
utilities and by-products are given in the preceding
section of this report.
b. Specific Comparison of the Two Processes
The following table presents the econonmics of the
two processes:
$/MMBtu
2%S
PLANT GEN.
CAP. : MW
125
250
500
1000
W.L.*
36.7
34.3
.32.7
31.0
W-L/A**
44.1
37.2
33.5
30.6
4%S
W.L.
43.2
40.5
38.9
37.0
W-L/A
56.4
49.2
45.3
42.4
6%S
W.L. W-L/A
49.6 68.6
46.8 61.3
45.0 57.2
43.0 54.1
* Wet Limestone
** Wellman-Lord/Allied
As can be seen from the above table, the Wet Limestone
process is less expensive to operate than the Wellman-
Lord process in all cases. The two processes are
essentially equal in cost, in plants 250mw in size and
larger, only when the percent sulfur in the coal is
very low (between 1 to 2%).
107
-------
The following general conclusions can be drawn from the
table and also from the graph which is a plot of C/MMBtu
vs. percent sulfur in the coal with plant sizes as para-
meters. This graph is noted as Figure 2.
(1) As expected, the operating cost in C/MMBtu drops
as the plant size increases. For the Wet Limestone
process using (4% S coal), the cost drops from 43.2
C/MMBtu for a 125 mw plant to 37.0 C/MMBtu for a
1,000 mw plant. The drop is even more drastic for
the Wellman-Lord/Allied process with the cost
dropping from 56.4 C/MMBtu for a 125 mw plant to
42.4 C/MMBtu for a 1000 mw plant.
(2) For a given plant size (in megawatts), the cost of
scrubbing in C/MMBtu increases linearly as the %S
in the coal increases. The scrubbing system cost
for the Wellman-Lord/Allied system is more sensi-
tive to %S in the coal than is the Wet Limestone
scrubbing system. For example, a 250 mw power
plant using the Wellman-Lord/Allied scrubbing system
is estimated to have an operating cost of 37.2 C/MMBtu
using 2% S coal and a cost of 61.3 C/MMBtu using 6% S
coal. This represents an increase in operating cost
of 6.02 C/MMBtu/%S. The Wet Limestone scrubbing
system for a 250 mw power plant is estimated to have
an operating cost of 34.3 C/MMBtu using 2% S coal
and 46.8 C/MMBtu using 6% S coal. This represents
an increase in cost of 3.12 C/MMBtu/% S for a given
plant size.
c. Detailed Economic Comparison of the Two Processes
When Installed on a 500 MW Power Plant
(1) The following table gives a detailed breakdown
of the capital and operating cost for the two
processes.
108
-------
500 MW
WELLMAN-LORD/ALLIED
2.545%S
f/KW 84.39
Mills AWH 4.04
t/MMBtu 36.72
Capital Costs: MS
EA 9,011
ES 1,968
EP 1,129
ER 1,261
H 7,232
L 3,903
BARC 32,173
TPI 36,034
TCR 42,196
Operating Costa: M$/YR
AS 394.'
AAO 1
AN 255
AFA 25
AE 713
AH 1,330
ACW 146
AW 4
AF 575
ASC -334
APS 20
ANR 3,129
TAC 12,387
SF: Mft/HR 14
TB(No. SCR. Trains) 4
K7 (No . REGEN . Trains } 2
N28 (No. Purge/Make-
up Trains) i
Breakdown of TAC
0.237 TPI 8,540
2.KTO) (CO) (1+F) 593
1.04 ANR 3,254
12,387
5.09%S
113.51
5.66
51.54
9,531
3,936
1,816
1,968
10,030
5,367
43,037
48,202
56,758
790
1
511
25
934
2,660
285
9
575
-668
39
5,161
17,384
28
4
4
1
11,424
593
5 ",367
17,384
MET LIMESTONE
2.545IS
77.37
3.79
34.50
EC 9,402
ES 900
P 106
T 112
7,791
3,829
29,402
32,931
38,683
AL 840
AA 11
777
34
575
ASL 1,160
3,397
11,634
14
4
7,805
296
3,533
11,634
5.09%S
83.07
4.65
42.29
9,461
1,680
150
170
7,909
3,992
30,982
34,700
41,533
1,680
22
875.
50
575
2,320
5,522
14,263
28
4
8,224
296
5,743
14,263
109
-------
Detailed examination of the table yields the
following conclusions:
(a) Using low sulfur coal (2.545 %S), the
Wellman-Lord/Allied process is just
slightly more costly than the Wet Lime-
stone process (36.72 vs. 34.50 C/MMBtu -
a difference of only about 2.2 C/MMBtu).
Most of the increased cost for the Wellman-
Lord/Allied process lies in higher fixed
capital charges (due to the presence of
considerably more equipment in the regener-
ation area, purge make-up area and S02 re-
duction area, than is required in the limestone
system). The variable cost of chemicals,
utilities and waste disposal are somewhat
higher for the Wet Limestone process but
this is offset by lower labor charges.
A comparison of the processes using a
fairly high sulfur coal (5.09 $3) gives
an even larger advantage to the Wet Lime-
stone process, its operating cost is ex-
pected to be about 42.29 $/MMBtu vs.51.54
C/MMBtu for Wellman-Lord/Allied - a diff-
erence of 9.2 C/MMBtu. Again, as with the
low sulfur case, capital charges on-the
substantially higher investment for the
Wellman-Lord/Allied process make up the
difference in cost. As previously in-
dicated, the variable cost of chemicals,
utilities and purge disposal is somewhat
higher for the Wet Limestone process, but
this is offset by lower labor charges.
Now we can address the problem of sludge
disposal cost for the Wet Limestone process.
110
-------
As previously indicated, a cost of $1.50/Ton
of wet sludge (40% solids) was used for the Wet
Limestone sludge disposal cost. For the 2.545%
sulfur case, a sludge disposal cost of $2.44/Ton
would bring the Wet Limestone process cost up to
a figure equal to the Wellman-Lord/Allied cost
(36.72 C/MMBtu). For the high sulfur coal
case (5.09% S) , a sludge disposal cost of $3.44/Ton
for the Wet Limestone process would bring its
operating cost up to that of the Wellman-Lord/Allied
process (51.54 C/MMBtu). It is worthy of note
that it does not appear to be economical or
feasible to pay more than about $1.50/Ton for
sludge disposal as used in the economic calcula-
tions in this study. The reason for this is the
fact that the use of a large disposal pond (20
years storage) provides a more viable economic
alternative for sludge disposal rather than pay-
ing extremely high sludge disposal costs.
For example, using the Wet Limestone process and
2.545% S coal, it is estimated that the use of a
large disposal pond would reduce the operating
cost to 33.02 «/MMBtu vs. 34.50 C/MMBtu when
using a sludge disposal cost of $1.50/Ton. The
incremental capital investment required for a
plant with a 20 year disposal pond vs. one which
has a small pond and thickener is about $7/kw.
For the 5.09 % S coal case, it is estimated that
the use of a large (20 year) storage pond would
reduce the operating cost of the Wet Limestone
process to 39.16 C/MMBtu vs. 42.29 C/MMBtu using
a sludge disposal cost of $1.50/Ton. The in-
cremental capital investment for installing a
large disposal pond rather than having a small
pond and thickener is about $12/kw for the 5.09
%S case.
Ill
-------
In some power plants, particularly those located
in cities, there simply is no room for a large
disposal pond. If this is the case, one posssi-
ble alternative would be to transport the sludge
out of the city to an open area where a large
pond could be installed.
(c) An examination of the operating cost for chem-
icals, utilities, sulfur credit and sludge dis-
posal (at 5.09 %S coal) indicates that the most
significant contribution to operating cost for
the Wellman-Lord/Allied process is the steam
cost. The most significant contribution to
operating cost for the Wet Limestone process is
the sludge disposal cost (at $1.50/Ton). If a
40% savings in steam could be realized for the
Wellman-Lord/Allied process using double effect
evaporators, the operating cost would drop by
about 3.1 C/MMBtu to 48.4 C/MMBtu vs. 42.29 <:/
MMBtu for the Wet Limestone process.
The cost of electric power is about the same
for both processes as is the cost of fuel used
for reheat. For the Wellman-Lord/Allied pro-
cess, the costs of filter aid, cooling water,
process water, and the cost for disposal of
purge solids are rather insignificant. The
sulfur credit of $10/long ton is mildly signi-
ficant. If this credit were reduced to 0, the
operating cost for the Wellman-Lord/Allied
process would rise by about 2C/MMBtu.
As previously mentioned, the sludge disposal
cost for the Wet Limestone process makes the
most significant contribution to the variable
operating cost. The next most important con-
tribution is made by the limestone cost.
112
-------
Fairly insignificant in the operating cost
picture are the costs of ammonia and make-up
water.
3. Conclusions Regarding Stack Gas Scrubbing as Used in
the Iowa Study
a. Since the Wet Limestone process (with sludge disposal
at $1.50/Ton) appears to be more economic than the
Wellman-Lord/Allied process, the costs for this process
were used in the linear computer program for the Iowa
study. From the graph, (See Figure 2), it can be
seen that for a 250 mw power plant (note that the
average size of the eight power plants in Iowa
is about 203 mw) that the operating cost is about 40.5
C/MMBtu using 4% S coal and 43.6 £/ MMBtu using 5% S
coal.
b. If the Wellman-Lord/Allied process costs were used,
then the cost for stack gas scrubbing would be about
49.2 C/MMBtu using 4% S coal and 55.2 C/MMBtu using
5% S coal.
113
-------
Figure 2
SCRUBBING SYSTEM COST VS. % SULFUR IN COAL
60
50
40
30
20
PLANT GENERATING CAPACITY: MW 125
WELLMAN-
LORD/ALLIED
WET
LIMESTONE
HR = 11,000 BTU/KWH
HHV = 10.000 BTU/LB
RBMAX =1.7
R BASE = 3-5
F = 1.52
LF = 0.70
CSL = $1.50/TON
L
3 4
% SULFUR IN COAL
6
-------
VII. LINEAR PROGRAMMING MODEL
A. A Brief Discussion of Linear Programming
1. Linear Programming
Linear programming deals with the problem of allocating
limited resources among competing activities in an optimal
manner. The great variety of situations to which linear
programming can be applied is indeed remarkable. Linear
programming uses a mathematical model to describe the pro-
blem of concern. The adjective "linear" means that all the
mathematical functions in this model are required to be
linear functions. The word "programming" is essentially a
synonym for planning. Thus, linear programming (LP in
brief) involves the planning of activities in order to obtain
an " optimal" result (according to the mathematical model
describing the problem of concern) from all feasible alter-
natives.
A typical LP problem can be described mathematically as
follows:
Find X, , X~, X-, ... , X that maximizes or minimizes the
linear function
Z = cnX, + c_X- + c,X_ + ... + c X
11 I i J j nn
Subject to the restrictions
allXl + a!2X2 + ''' + anVbl
a21Xl + a22X2 + ' + a2nVb2
amlXl + am2X2 + ' ' ' + amnVb;
m
115
-------
and X1>0, X2>0 ..., Xn>0
where a. , b., c. are given constants.
The function being maximized or minimized is called the
objective function and the restrictions are called the
constraints or restraints.
If a real world problem can be defined in terms of such
equations then this will be a linear programming model of
the problem. For further discussion on linear programming
the reader should refer to any text book on operations re-
search (19) .
2. Simplex Method
The "Simplex Method" is the method for solving any linear
programming problem. This is an algebraic procedure which
progressively approaches the optimal solution through a well
defined iterative process until optimality is finally reached.
Even though the method is straightforward it requires con-
siderable time if done manually. The difficulty in finding the
solution is greatly increased with number of constraints and
the number of unknowns entering the LP model. However, an
LP model can be easily solved using an electronic computer.
3. Special Types of Linear Programming Problems
As pointed out in the above discussion on linear programming,
LP can be applied to different practical problems. One of the
common and widely used applications of LP is to transportation
or transhipment problems. A typical transportation problem
determines optimal shipping patterns between different sources
of supply and points of demand under the constraints of de-
116
-------
mand and supply.
4. Handling of Non-Linear Relationships
Certain functions related to economic decisions are non-
linear in nature and not directly applicable to linear
programming treatment. Some common examples include the
capital cost versus capacity of a process unit in any
investment model, costs functions for shipping a product
by common carrier, etc. Many of the non-linear relation-
ships can be adequately represented using linear segments
approximating the desired curve. There are techniques for
handling non-convex functions in an LP environment and the
ones most commonly used are:
Separable programming
Integer programming
Mixed integer programming
5. Kellogg's Experience With Linear Programming
Over the years, the M. W. Kellogg Company has utilized linear
programming and other related computer techniques in process,
economic and cost studies for clients within the process
industry. Some of these applications have included
Refineries
Gasoline Blending Model
- Kellogg1s Olefin Plant LP System
Fuels Refinery System
The proper selection and application of computer software for
compiling and solving LP problems requires a thorough know-
ledge of the problem and the sensitivity of the needs of the
user. The major aspects of the LP software package include
117
-------
MAGEN and MPSX.
MAGEN (6) is a software system developed by Haverly Systems,
Inc. to generate a matrix. Through classification of related
variables and restrictions, LP problems can be generalized
by type, thus making it easy for the user to supply pertinent
data in a convenient tabular form and define his own terms.
The IBM (MPSX) Mathematical Programming System Extended (7)
is a set of procedures containing linear programming optimi-
zation codes from which a user can select a strategy for
solving an LP problem.
KELPLANS, Kellogg Planning and Analysis Systems, are the ef-
fective resultants of process engineering and computer appli-
cations toward a realistic optimum solution to complex economic
problems.
B. The Definition of the Problem in Terms of an LP model
The earlier sections have already discussed the objective of this
study in great detail. Stated again, we want to find the minimum
overall system cost ($/day) for different transportation patterns,
for various S02 emission specifications, under the constraints of
the system. These constraints are developed by generating suit-
able equations containing variables that relate the different
parameters of the system. The mathematical model will use the
values of the constants for the equations from the input data
tables given in Section III. As stated in Section III of this re-
port there are so many variables affecting the overall cost of
controlling S02 emissions from power plants in the State of Iowa
that a mathematical model (LP model in this case) has to have a
certain convenient nomenclature to cover all the possible variables
to be determined in the objective function (costs) and the con-
straints.
118
-------
1. Objective of the LP model
The purpose of the model is to minimize total system costs
by determining the optimal sources and distribution routes
for the coal needed by various power generation stations in
the State of Iowa while complying with the effluent specifi-
cations established by the EPA. It is anticipated that
some of the coal may require treatment to reduce the emission
of S02, and, if so, the number and locations of the treatment
plants will be determined. It is also expected that stack
gas scrubbing may be required to meet the more stringent
regulations (particularly if low sulfur coal is limited).
If so, the number and locations of the scrubbing systems
will be determined.
2. Basic Assumptions of the Model
The model is based upon the following assumptions:
a. The energy requirement of each power generating plant
(expressed as MMBtu/day) must be satisfied.
b. Assuming total conversion of sulfur in the coal to
SO-' emissions must not exceed a certain specifi-
cation in pounds of SO? per MMBtu of energy require-
ment.
c. The emission specification can be attained by selec-
tive use of low sulfur coal, by reducing the sulfur
content of the coal (cleaning), and/or by treating
the exhaust gases to reduce the emission of SO.
(scrubbing).
119
-------
The cleaning process removes most of the pyrites
which contain proportionately more sulfur than
does the coal. The ash content of the coal is reduced
somewhat, and the heat content somewhat increased.
The scrubbing process removes most (90%) of the
S0_ in the exhaust gases. The wet limestone scrub-
bing process costs were used in the model because
they appeared somewhat lower than Wellman-Lord/Allied
costs (based on the assumptions made). However, the
program can be adapted to use other scrubbing costs.
d. Coal may be shipped by rail or (where applicable) by
barge on the Mississippi and/or Ohio rivers. Where
appropriate rail facilities are available for storage
and switching of coal cars, "unit trains" may be used
for rail shipments at rates significantly below
normal freight costs.
e. Specification of the availability of coal (in tons/
day) at any source (mine) is optional.
f. The KELPLANS investment type LP model (5) is used to
simulate the scrubbing and cleaning facilities. It
120
-------
uses continuous and integer variables to:
(1) represent the non-linear function that
relates the cost of scrubbing with the
size of the equipment by means of two
linear segments. (The cost of cleaning
is given to be linear with respect to
the equipment size).
(2) bound the size of the scrubbing as well
as cleaning systems between an upper and
lower limit. (See Figures 3 and 4).
3. Nomenclature
As stated above all the variables that affect the overall cost
are generated using a convenient scheme. Each category of
variable that affects the system is called a class. The fol-
lowing discussion explains how the different variables are
generated.
a. Location Codes: each geographic point in the model
has been assigned a two character location code as
shown in page 129. For example, the code "ME" rep-
resents Madisonville, Ky where there is a coal mine.
The notation "(ML)" represents the set of all coal
mines: MA, MB, ..., and MH. Similarly, the symbol
"(DL)" represents the set of all power plants and
"UD" represents other locations. "(PL)" is the
set of all locations referenced and is equivalent
to the logical union of (ML) U (DL) U (<|>L) .
On page 131 under class SL, a list of the possible
121
-------
power plants which can have scrubbing is given.
DF, for example, is a power plant in Clinton where
scrubbing facilities are permitted. The last three
classes (M, M2 and M3) on page 131 are used to simplify
coding of the mixed integer programming in the model
and are not important to this discussion.
On page 132, class CL is the list of possible cleaning
locations. Class N is used to simplify the mixed
integer programming in the model.
Class CST on page 133 represents all the cost factors
affecting the problem.
b. Vectors: the vectors are the columns of the LP model
and represent the unknowns in the problem. The vectors
are:
W(ML) (DL) = tons per day of' uncleaned coal ship-
ped directly from a mine to a power plant.
WS(ML)(SL) = same as W(ML)(DL) but scrubbed at
power plant (SL) .
X(ML)(PL)(DL) = tons per day of uncleaned coal
shipped from a mine to a power plant via some
intermediate point, except where the inter-
mediate point is at the plant or the mine.
XS(ML)(PL)(SL) = same as X(ML)(PL)(DL) but
scrubbed at power plant (SL)
Y(ML)(CL)(DL) = tons per day of coal shipped
from mine to transfer point (CL), cleaned at
122
-------
transfer point and shipped to a power plant.
YS(ML) (CL) (SL) = same as Y(ML) (CL) (DL) , but
scrubbed at power plant (SL)
SSl(SL) = size of scrubbing system installed at
location (SL) in MMBtu/day.
SS2(SL) = variable used in KELPLAN's model to
simulate the scrubbing system at location (SL).
It is equivalent to [(MMBtu/day)(% Sulfur)].
S(M)(SL) = variable used in KELPLAN's model to
simulate the scrubbing system at location (SL).
CC1(CL) = size of cleaning plant installed at
location (CL) in tons per day of coal feed.
C(N)(CL) = same as S(M)(SL) but for cleaning
system.
Q(DL) = energy deficiency, MMBtu/day
T(CST) = total cost for each cost factor (pit-
head, freight , etc) in $/day.
IN12(SL) or IN23(SL) = scrubbing plant indicator
(integer variable). If equal to zero, plant does
not exist; if equal to one, plant exists (at SL).
IM12(CL) = cleaning plant indicator (integer
variable). If equal to zero, plant does not
exist; if equal to one, plant exists (at CL).
RIIS = right hand side which shows capacities,
availabilities, etc. in units appropriate to
123
-------
the various equations.
The above notation W(ML)(DL) implies one vari-
able for each combination of mine and power
plant.
4. Input Data to Solve the LP Problem
The input data and the various decision variables that will
affect the solution of the problem are input to the model
in the form of tables. Section III has discussed in depth
the sources and validity, etc. of the data that was used for
this study. The following discussion covers the different
tables that are used in the solving of the model. The model
for Iowa consists of 18 power plants, 8 mines, 28 possible
transfer plants, 8 possible scrubbing locations, and 8 pos-
sible cleaning locations. There are 142 constraints irows),
6705 variables, and 24 integer variables.
On page 133, table RAW summarizes the properties of unwashed
coal; table WASHED, the properties of clean coal. Freight
handling facilities available at each location are summarized
in table LOAD (page 134).
The data shown on page 135 consists of the energy requirements
in table DEMAND: the sulfur specifications (different cases)
are listed in table SPEC; and the miscellaneous economic fac-
tors are shown in table ECON.
On pages 136 and 137, the distances between various locations are
shown. Since all locations are accessible to rail lines, the
table of rail distances forms a symmetric matrix, half of which
is entered as a triangular table. For locations on the Mississ-
ippi or Ohio rivers, a separate table (table RIVERD) of dis-
124
-------
tances by river has been supplied (page 338 ).
Table COSTSCR consists of the coordinates (MSC,SIZ) used to
represent the non-linear cost of scrubbing by the use of two
straight lines. (See Figure 3).
Likewise, t?ible COSTWAS consists of the coordinates (MS,SI)
used to represent the cost of cleaning by one straight line
(page 138 ) . See Figure 4.
C. Solution Using KELPLANS
KELPLANS uses MAGEN(6) to generate the matrix and MPSX(7) to
run the linear programming step.
Once the input data matrix has been generated, the MPSX is
performed in two distinct steps. First the problem is opti-
mixed while considering all integer variables as being con-
tinous: "continous optimum". At the continuous optimum, the
integer variables which denote the existance of cleaning or
scrubbing facilities (0=No , l=Yes) may be at some intermediate
value (such as 0.6). This implies that the cleaning and scrub-
bing costs may be understated and plant sizes may be below the
feasible minimum.
In the second step, the mixed integer program (MIP) is involved
to find the best solution where all of the Yes/No variables are
either 0 or 1. The optimal integer solution must result in a
cost equal to or greater than the continuous optimum solution.
Maximum flexibility exists in the model. The list of power
plants, mines, transfer points, scrubbing and cleaning locations
can be increased or decreased by adding or deleting the number
in the respective class. For example, if Salix, Iowa (DN) is
not a convenient location for cleaning, in class CL (page ),
125
-------
DN must be deleted. Now, if Lansing, lov/a (DD) is a good
location for scrubbing, DD should be included in class SL
(page 131).
The same flexibility exists in the tables. For example, if
the demand at DA has changed to 20,000 in table DEMAND
(page 135) the 18,684 for DA should be changed accordingly.
Similarly, flexibility exists in the model regardina all
other variables. Coal mine properties, coal costs, mine
capacities, washed coal properties, transportation possi-
blities and costs, milages, and economic factors can all
be changed as necessary to evaluate the system.
126
-------
<
Q
£
S
Figure 3
WET LIMESTONE SCRUBBING COST VS. CAPACITY
$/D = 2.82 (MM BTU/D)°J*X
REPRESENTS TWO
STRAIGHT LINES USED
BY COMPUTER
$/D = 0.0315 (MM BTU/D)(%S
5%S
HR= 11.000BTU/KWH
100
200
(52,800)
300
400
(105,600)
500
600
(158,400)
PLANT CAPACITY: MW (MM BTU/DAY)
-------
Figure 4
COAL CLEANING COST VS. CAPACITY
400
300
$/D = $1.90 (TPD)
no
oo
200
100
MIN = 7200 TPD
I
MAX = 240,000 TPD
i I i
100,000
200,000
COAL FEED: TPD
-------
HAVERLY SYSTEMS INC LP/360 74163 VERS. J MCO. 3
* IOWA F MODEL
SYSTEM DATE - 3/01/74
TIME REAL 00<00:00 TASK OOiOOsOO
TIME REAL 00:00:00TASK 00:00:00
GENERATE
TIME REAL 00:UP:00 TASK 00:00:00
DICTIONARY
CLASS OL
*
DA
OB
DC
nn
OE
DF
DC
OH
DI
nj
OK
OL
OH
ON
no
H> OP
w oo
* CR
LIST OF POWER PLANT LOCATIONS
AMES (AMES MUNICIPAL PLANT)
AMES (lOfcA ST U PLANT)
KONTPELIER
LANSING
OUDUOUE
CL INTON
CCPAR RAPIDS (PRAIRIE CREEK)
CFOAP OAPIOS (SIXTH ST)
f«APSHALLTCWN
BCTTENDORF
COUNCIL BLUFFS
DES MOINES
WATFKLQO
SAL IX
FnOVVlLLE
Bit" LIN", TON
MUSCATINE
PFllA
CLASS ML
*
MA
MB
MC
MO
ME
MF
MG
MH
CLASS OL
*
PA
Pfl
LIST OF COAL MINE LOCATIONS
FREOFRICK IOWA
LFCN IOWA1
OGDEN IOWA
MAP TUN IIIINini<;
MAOISONVILLE KY
HANflA WYOMING
COLSTRIP MONTANA
LIST OF OTHER POSSIBLE TRANSFER POINTS
PAPUCAH KY
GORHAM ILLINOIS
CLASS PL
POSSIBLE LOCATIONS FOR TRANSFER POINTS
ML) (» I AT ANY MINE
.1DL ) L>.). J AT AMY P.UWEBPlAfll
-------
IQL) (» I AT ANY OTHER SPECIFIED LOCATION
OJ
o
-------
CLASS SL
*
OF
OG
ni
OJ
DL
DM
OP
LIST OF POSSIBLE SCRUBBING LOCATIONS
no
CLASS M
*
I
2
3
CLASS M2
*
12
LIST OF VARIABLES USED IN SCRUB. MODEL
LIST OF INTEGER VAR. SCRUB. MODEL
23
M
W CLASS M3
* M
SI
S2
LIST OF VARIABLES COST SCRUB. KODEL
-------
CLASS CL
ON
LIST CF POSSIBLE CLEANING LOCATIONS
OP
HA
MB
MC
MO
PA_
P'D
CLASS N
1
CLASS R
1
2
LIST OF RIGHT HAND SIDES
U>
to
-------
CLASS CST
LIST OF POSSIBLE COSTS
PTT PITHEAD COST
FRT FREIGHT COST
ASH ASH DISPOSAL COST
_SC I SC PIJB_CP.SJ
SC? SCRUB COST
WSH WASHING PLANT COST
_P.E_F_P FFUSF _p ISPflSAl COST
STO STORAGE / LOADING / UNLOADING COSTS
6RN BROWNOUTS
OAT A
TABLE RAW
PROPERTIES OF UNWASHED COAL
CAP
MA
MB
MC
MO
KF
F-1 MF
j*\ MG
MH
14.
12.
13.
14.
14.
8.
4.
10.
8
2
9
a
4
2
&
ASH
SUL
BTU
CST
CAP
5
if
6
3
4
0
0
0
.3
.9
. 1
* 1
.9
.3
.8
10.038 6.25
9.676 6.25
10.184 6.25
11.951 6.70
ll.P01__6..7.0_
10.506 4.20
11.460 5.00
8.79C 3.60
50.
50.
50.
50.
50.
8.
8.
0.
= ASH IN WT PCT
= SULFUR IN KT PCT
HEAT
CUST
MINE
CONTENT IN MBTU/LB
AT SHIPPING POINT IN I/TON
CAPACITY IN MTON/OAY IBLANK=NO LIMIT 1
TABLF WASHEP
PROPFRTTCS OF Cl FAN COAL
*
*
*
*
*
MA
MB
MC
MD
MF
ASH
7.9
7.0
7.5
7-0
7.2
LOSS
SUL
3.5
1.9
4.5
2.7
5UL.DTU =
= KT PCT
BTU LOSS
11.033 20.0
10.65C 20.0
11.166 20.0
i?.<>05 ?n.n
12.340 20.0
SANE AS TABLE
RAW
LOSS ON CLEANING
-------
TABLF LOAD
*
*
RJ
*
OH
DC
no
DE
OF
OG
OH
DI
OJ
OK
01
DM
DN
no
PP
DO
DP
*
MA
MB
*C
M MO
£ MF
* HP
MG
MH
*
PA
PB
SUMARIZES LOADING / UNLOADING FACILITIES
AT EACH LOCATION (l=YES)
IL LNIT BARG
1
1
1
1
1
1
11
1
1
1 1
11
1 1
L 1
L 1
1 1
RAIL > CONVENTIONAL RAIL CAR
UNIT = UNITS TRAIN
BARG - BARGES
-------
TABLE DEMAND
REQUIREMENT IN MMBTU/OAY
*
04
DB
DC
no
OF
OF
OG
PH
01
OJ
OK
OL
OM
ON
00
DP
DO
OR
TABLE
*
*
1
M 2
OJ 3
ui «
18684.
1299«.
17726.
20023.
24504.
59525.
64862.
ft4S37.
43219.
67512.
33461.
07017.
31570.
1I56P.?.
25A08.
51307.
31488.
18259.
SPEC
SPFC IN LBS S02 / MPBTU
MUX
20.
5.
3.1
1.2
TABLF
*
*
*
PAIL
UNIT
BAtG
*
ASHE
PF.FIJ
STOB
*
FINV
flNV
ECON
ECONOMIC FACTORS
TON TPM TPH
t/TON S/T/M S/T/HR
O.C28
O.OC5
0.006
1.
0.31
C.30
1.0
1.0
CBPN
10000.
-------
TABLE RROIST
DISTANCES BY RAIL
*
DA
DB
DC
DO
DE
or,
DH
ni
DJ
DK
DL
DM
nn
DP
oa
DR
MA
MB
MC
MO
MF
MF
MR
MH
V-- PA
*
OJ
OK
01.
OH
DN
on
00
OR
MA
MC
MO
ME
MF
y.H
PA
PR
3
167
244
177
187
105
105
1P3
155
36
P5
192
111
2C1
173
83
117
125
22
5C2
5S6
795
943
915
549
463
01
146
192
59
48
229
67
157
138
74
73
148
59
4UO
574
832
980
951
527
441
187
244
177
187
105
105
37
183
155
36
85
192
111
2C1
173
83
117
125
22
502
596
795
943
915
549
463
OJ
318
178
130
375
127
91
30
155
133
203
205
361
455
958
1106
109U
403
322
190
109
48
82
82
150
16
302
182
134
385
111
75
14
139
117
Ifl7
209
371
4A5
«J42
1090
1018
418
332
OK
161
237
83
197
281
288
225
191
244
133
539
633
640
788
870
5C6
500
81
142
170
170
188
174
355
247
140
390
277
265
204
3C5
203
353
266
535
629
995
1143
1019
5fl2
496
DL
107
208
75
165
168
47
81
89
58
466
560
801
94 9
950
513
427
61
89
89
140
93
331
201
94
344
196
184
123
224
202
272
199
454
548
971
1119
1043
501
415
DM
250
115
150
120
122
121
196
107
488
582
877
1025
V60
532
446
82
82
150
32
342
206
134
379
159
123
62
187
165
235
209
393
487
982
1130
1094
440
354
ON
283
370
380
255
289
297
170
622
716
682
859
707
669
583
5
68
78
260
124
52
297
107
98
68
135
113
183
127
436
530
900
1048
1012
480
394
DC
90
97
28
6
82
133
413
507
837
985
1025
460
374
68
78
260
124
52
297
107
98
68
135
113
183
127
436
530
900
1048
1012
480
394
OP
61
118
96
166
223
338
432
921
1069
1110
385
299
00
DR
MA
MR
MC
MO
MF.
MF
OR
-------
MA
MB
MC
MO
ME
MF
pr,
MH
PA
PB
*
MH
PA
PR
103
173
195
365
479
978
1076
lOfiO
432
14ft
MG
1034
1374
1288
34
110
105
441
535
B65_
1013
997
408
402
MH
1456
1370
76
139
407
501
flll
<579
1031
454
368
PA
100
145
438
532
884
1032
1039
485
399
PB
518
612 145
773 1179 1273
921 1347 1421 557
929 1429 1503 887
565 54 85 1226
479 40 IBS 1140
-------
TABLE RIVERO
DISTANCES BY RIVER
DC nn DF OF oj OP DO PA PB
*
oc
00
OE
DJ
DP
DO
PA
1R8
1C8
48
18
67
17
516
80
140
170
255
205
704
60
90
175
125
624
30
115
AS
564
85
35 50
534 449
499
PB 366 574 494 434 404 319 369 130
TABLE COSTSCR
INCLUDES PARAMETERS NEEDED TO
MODEL THE NON-LINEAR PART OF
THE CCST OF SCPUBBING
MSC SI2
1 5581. -M2CC.
_2_ 23400. -79200.
3 40740. -1584CC.
TABLE CCSTHAS
INCLUDES PARAMETERS NEEDED TO
*
*
(jj
CO
1
2
MODEL
MS
136BO.
456000.
THE COST OF
SZ
-7200.
-24000C.
WASHING
-------
VIII. REFERENCES
1. 1972 Keystone Coal Industry Manual , Mining Information Services
of the McGraw-Hill Mining Publications, 1972.
2. Gates Engineering Company, Feasibility Study of Iowa Coals,
May, 1974.
3. M. W. Kellogg Company, Evaluation of R & D Investment Alternatives
for SO Air Pollution Control Processes, Draft Report, January, 1974.
4. M. W. Kellogg Company, Evaluation of the Controllability of Power
Plants Having a Significant Impact on Air Quality Standards,
February, 1974.
5. Schneider, L. W. , Mixed Integer Programming Applied to Investment
Type LP's, NPRA-CC-71-98, November, 1971.
6. Haverly Systems, Inc., LP/360 Programming System, Section I - Mixed
Integer Programming, May, 1971.
7. International Business Machines, Mathematical Programming System
Extended (MPSX) , Program Number 5734-XM4, February, 1971.
8. Rand McNally, Handy Railroad Atlas of The United States, 1973.
9. National Coal Association, Steam-Electric Plant Factors, 1973
Edition for 1972 Data, January, 1974.
10. Bernard, J. H., Babcock & Wilcox Company, A Steam Generator Designer
Looks at Western Coals , Technical Paper, October 7, 1971.
139
-------
11. Attig, R. C., Duzy, A. F., Babcock & Wilcox Company, Coal Ash
Deposition Studies and Application to Boiler Design, Technical
Paper, April 22, 1969.
12. Duzy, A. F., Babcock & Wilcox Company, Fusibility-Viscosity of
Lignite Type Ash, ASME Publication, August 18, 1965.
13. Olson, W. T., Universal Oil Products Company, Conditioning Fly Ash
to Improve Electrostatic Precipitator Performance, Power Engineering,
April, 1972.
14. McKinney, B. G., Little, A. F., Hudson, J. A., Tennessee Valley
Authority, The TVA Widow's Creek Limestone Scrubbing Facility,
Paper Prepared for Flue Gas Desulfurization Symposium, May, 1973.
15. Calvin, E. L., Catalytic, Inc., A Process Cost Estimate for Limestone
Slurry Scrubbing of Flue Gas, January, 1973.
16. Archer, W. E., Consultant, Joy Manufacturing Company, Electrostatic
Precipitator Conditioning Techniques, Power Engineering, December,
1972.
17. The Problem Beyond Disposal, Electrical World Engineering Management
Conference on Waste Disposal in Utility Environmental Systems,
McGraw-Hill, October, 1973
18. Duzy, A. F., Rudd, A. H., Babcock & Wilcox Company, Steam Generator
Design Considerations for Western Fuels, Technical Paper, April, 1971.
19. riillier, F. S., Lieberman, G. J., Introduction to Operations Research ,
Holder-Day Inc.
140
-------
IX. GLOSSARY
acfm : Flow rate in actual cubic feet per minute (measured
at flowing conditions)
Btu : Energy measured in British Thermal Units
load
^actor : Fraction which multiplied by peak generating capacity
gives the average generating capacity for the year.
csa : Cross-sectional area
cu yd : Volume measured in cubic yards
ESP : Electrostatic Precipitator
°F : Temperature in degrees Farenheit
FPC : Federal Power Commission
ft : Linear measure in feet
fps : Velocity in feet per second
sq ft : Area in square feet
gal : Volume measured in U.S. Gallons (7.481 gallons = one
cubic foot)
gpm : Flow rate measured in gallons per minute
grain : Mass equal to 1/7000 of one pound
hr : Time in hours
141
-------
"H20 : Pressure in inches of water (27.72 inches of water =
1 pound per square inch)
kv : 1,000 volts
kw : Power measured in kilowatts (1 kw = 1,000 watts)
kwh : Energy measured in kilowatt-hours
long ton : Mass (1 long ton = 2240 pounds
(LT)
M : 1,000 units (e.g. M$ = thousands of dollars)
MM : 1,000,000 units
mw : Power measured in megawatts (1 mw = 1,000,000 watts
or 1,000 kilowatts
ppm : Concentration measured in parts per million (by volume)
psia : Pressure in pounds per square inch absolute
psig : Pressure in pounds per square inch gage
Ib/hr : Flow rate measured in pounds per hour
scfm : Flow rate in standard cubic feet per minute (measured
at 60°F and 14.7 psia)
sec : Time in seconds
ton : Mass (1 ton = 2,000 pounds)
tph : Flow rate measured in tons per hour
142
-------
X. APPENDICES
143
-------
APPENDIX A
POWER PLANT INPUT DATA
144
-------
Table 5
Power Plant Input Data
Des Moines Plant
Iowa Power & Light Company
General Plant Design Data
Plant Location
Plant Capacity, MW
No. of Boilers
No. of Generators
Des Moines, Ipwa
325
Coal Data
(1)
Source
Method of Transportation
Moisture, %
Ash, %
Sulfur, %
Heating Value, Btu/lb.
Iowa, Illinois, Wyoming
Rail, Truck
16.9
15.2
4.1 Max. Monthly Avg. 4.7
9395
Plant Operating Data in 1972
Plant Average Heat Rate, Btu/KWH_
Plant Average Load Factor, %
11,156
58.5
145
-------
Des Moinea plant
Boiler Data(2)
Turbo-Generating Capacity, MM
Coal Consumption, TPH
Air Flow
Total Air, SCFM
Excess Air, %
Flue Gas Flow, ACFM
Flue Gas Temperature, °F
Boiler Efficiency, %
Total Hours Operation During 1972
Average Capacity Factor, %
Year Boiler Placed in Service
.Remaining Life of Unit, Yrs.
(based on 40 year life)
Related to Generator No.
Served by Stack No.
Table
Power Plant Input Data
Boiler No. 6
Boiler No.7
Boiler No.8
Boiler No.9
136 Mw 'for
Stand-by
oil)
87,500
7
253,000
330
83.2
6,881
52
1964
30
1-5
1
4 boilers
24
52,000
10 - 30
173,000
330
82.3
7,398
52
1938
4
1-5
2
through common headers
24
52,000
10 - 30
173,000
330
82.3
6,425
52
1949
15
1-5
2
24
52,000
10 - 30
178,000
350
82.3
7,210
52
1950
16
1-5
3
-------
Des Moines plant
Table
Boiler Data
(2)
Turbo-Generating Capacity, HW
Coal Consumption, TPH
Air Flow
Total Air, SCFM
Excess Air, %
Flue Gas Flow, ACFM
Flue Gas Temperature, °F
Boiler Efficiency, %
Total Hours Operation During 1972
Average Capacity Factor, %
Year Boiler Placed in Service
Remaining Life of Unit, Yrs.
(based on 40 year life)
Related to Generator No.
Served by Stack No.
awer Plant Input
Boiler No. 10
70
42
79,500
23
283,000
343
86.5
6,134
80
1954
20
6
4
Data
Boiler Nc. il
110
50
109,000
19
343,000
290
88.4
7,854
71
1964
30
7
5
Boiler Nc.
Boiler No.
-------
Des Moines piant
Boiler Data(Cont'd)
Stack Height, Ft. above grade
I.D. of Flue at Top, Ft.
Distance to £ of Stack Breeching, Ft.
above grade
Fly Ash Removal Equipment
Type
Design Efficiency, %
Scheduled Maintenance Shutdown
Interval, Months
Duration, Weeks
Table 5
Power Plant Input Data
Boiler No. 6
138
15
80
None
24
Boiler No. 7
250
105
Cyclones
65
18
Boiler No.8
250
10
105
Cyclones
65
18
2oiler No. 9
250
105
Cyclones
65
18
(1) Coal quality and heating value are average"values for .coal burned in 1972.
(2) Operating data are at 100% load
-------
Des Moines piant
vo
Table
Boiler Data(Cont'd)
Stack Height, Ft. above grade
I.D. of Flue at Top, Ft.
Distance to £ of Stack Breeching, Ft.
above grade
Fly Ash Removal Equipment
Type
Design Efficiency, %
Scheduled Maintenance Shutdown
Interval, Months
Duration, Weeks
Power Plant Input Data
Boiler No. 10 Boiler No. 11
250
12
23
ESP
99.3
12
250
10
14
ESP
99.3
12
Boiler No.
Joiler No.
(1) Coal quality and heating value are average values for .coal burned in 1972.
(2) Operating data are at 100% load
-------
Des Moines Plant
Table 6
Stack Gas Scrubbing System
Boiler Boiler Boiler Boiler Boiler
Scrubbing System No.7.9 No.9 No.10 No.11 No.
No. Scrubbing Trains Required 1 1 1 1
Train Size(1) IV VI V III
Train Type
Wet Limestone C C C A
Wellman-Lord A A A A
Limestone System
Max. Design Capacity : tph 48.1
Wellman-Lord/Allied System
Sulfur Flow : Ib./hr. 18,000
Regeneration Area : No. Trains Required 2
Size<2> I
Purge/Make-up Area : No. Trains Required
Size<2>
SO? Reduction Area : No. Trains Required
Size <«
(1) Refers to standard size scrubber modules.
(2) Refers to standard size modules.
-------
Table 7
Power Plant Input Data
Maynard Plant
Iowa Public Service Co.
General Plant Design Data
Plant Location
Plant Capacity, MW
No. of Boilers
No. of Generators
Waterloo. Iowa
107
Coal Data
(1)
Source
Method of Transportation
Moisture, %
Ash, %
Sulfur, %
Heating Value, Btu/lb.
Illinois
Rail
12.0
11.0
2.5
10,861
Max. Monthly Avg. 2.8
Plant Operating Data in 1972
Plant Average Heat Rate, Btu/KWH 12,293
Plant Average Load Factor, %
40.0
-------
Maynard
Plant
Table 7
Boiler Data(2)
Turbo-Generating Capacity, MW
Coal Consumption, TPH
Air Flow
Total Air, SCFM
Excess Air, %
to Flue Gas Flow, ACFM
Flue Gas Temperature, °F
Boiler Efficiency, %
Total Hours Operation During 1972
Average Capacity Factor, %
Year Boiler Placed in Service
Remaining Life of Unit, Yrs.
(based on 40 year life)
Related to Generator No.
Served by Stack No.
>wer Plant Input
Boiler No. 9
6
55,900
118
102,000
400
83
2,286
18.4
1937
3
4
2
Data
Boiler No. 10
6
52,200
95
95,000
393
83
721
5.7
1943
9
4.5
2
Boiler No. I I
12
Boiler No. 12
25
6 0(§ai)fi
52,900
95
84,000
403
83
2.838
25.2
1947
13
62.900
35
101.000
300
85
4.054
26.0
1951
17
* 6
1
2
-------
Maynard plant
Table
Ul
OJ
Boiler Data(2)
Turbo-Generating Capacity, MW
Coal Consumption, TPH
Air Flow
Total Air, SCFM
Excess Air, %
Flue Gas Flow, ACFM
Flue Gas Temperature, °F
Boiler Efficiency, %
Total Hours Operation During 1972
Average Capacity Factor, %
Year Boiler Placed in Service
Remaining Life of Unit, Yrs.
(based on 40 year life)
Related to Generator No.
Served by Stack No.
Power Plant Input Data
Boiler No. 14 Boiler No.
58
24
132,300
25
373,000
325
87
8,085
66.6
1958
24
Boiler No.
Boiler No.
-------
Maynard Plant
Table
Ul
Power Plant Input Data
Boiler Data(Cont'd)
Stack Height, Ft. above grade
I.D. of Flue at Top, Ft.
Distance to £ of Stack Breeching, Ft.
above grade
Fly Ash Removal Equipment
Type
Design Efficiency* %
Scheduled Maintenance Shutdown
Interval, Months
Duration, Weeks
Boiler No. 9
220
Boiler No. 10
220
691 Q above basement floor
Cyclones
88
12
Cyclones
88
12
Boiler No-. 11 Boiler No. 12
Common stack
220 for Units 9,10,12
23' 3'
Cyclones
88
12
69' 0" above
basement floor
None
12
(1) Coal quality and heating value are average values for .coal burned in 1972.
(2) Operating data are at 100% load
-------
Mavnard
Plant
tn
ui
Boiler Data(Contd)
Stack Height, Ft. above grade
Z.D. of Flue at Top, Ft.
Distance to ft of Stack Breeching, Ft.
above grade
Fly Ash Removal Equipment
Type
Design Efficiency, %
Scheduled Maintenance Shutdown
Interval, Months
Duration, Weeks
Table 7
Power Plant Input Data
Boiler Mo.
Boiler No. 14
250
30
ESP
99
12
Boiler No-.
toiler No.
(1) Coal quality and heating value are average values for .coal burned in 1972.
(2) Operating data are at 100% load
-------
Maynard Plant
Table 8
Stack Gas Scrubbing System
Boiler Boiler Boiler Boiler Boiler
Scrubbing System No.9,10,12 No.11 No.14 No. Ho.
No. Scrubbing Trains Required 3- 1 L
Train Size(1) IV VIII_ III.
Train Type
Wet Limestone C C
Wellman-Lord A A
Limestone System
,_, Max. Design Capacity i tph 7t9
m
Wellman-Lord/Allied System
Sulfur Plow i Ib./hr. 303°
Regeneration Area : No. Trains Required x
Size<2)
Purge/Make-up Area : No. Trains Required
Size<2>
SOa Reduction Area : No. Trains Required
Size<2>
(1) Refers to standard size scrubber modules.
(2) Refers to standard size modules.
-------
Table 9
Power Plant Input Data
Muscatinp Plant-
Muscatine Municipal Electric Plant
General Plant Design Data
Plant Location
Plant Capacity, MW
No. of Boilers
No. of Generators
Muscatine, I.owa
117
Coal Data
(1)
Source
Method of Transportation
Moisture, %
Ash, %
Sulfur, %
Heating Value, Btu/lb.
Illinois
Barge, Rail
16.4
10.2
3.0 Max. Monthly Avg. 3.2
10,899
Plant Operating Data in 1972
Plant Average Heat Rate, Btu/KWH
Plant Average Load Factor, %
11,214
57.9
157
-------
Muscatine
Plant
Table
Boiler Data(2)
Turbo-Generating Capacity, MW
Coal Consumption, TPH
Air Flow
Total Air, SCFM
Excess Air, %
ml
% Flue Gas Flow, ACFM
Flue Gas Temperature, °F
Boiler Efficiency, %
Total Hours Operation During 1972
Average Capacity Factor, %
Year Boiler Placed in Service
Remaining Life of Unit, Yrs.
(based on 40 year life)
Related to Generator No.
Served by Stack No.
wer Plant Input
Boiler No. 5
7.5 (Standby)"
4.5
Data
Boiler No. 6
12.5 (Peaking
7
30
25,000 (Est.)
360
80
2000
50
1941
7
5 or 6
30
40,000 (Est)
380
80
4000
50
1946
12
5 or 6
2(3) l(3)
Boiler No. 7
tuase
22 Load)
11.5
Boiler No. 8
(BasS
84 Load)
84
130,000 Est
20
70,000 (Est.)
340
84
7300 (Est.)
70
1958
24
7
3<3)
11.5
251,000
322
90.3
8000
90
1969
35
8
4
-------
Muscatine
Plant
vo
Boiler Data(Cont'd)
Stack Height, Ft. above grade
I.D. of Flue at Top, Ft.
Distance to ft of Stack Breeching, Ft.
above grade (Grade = 95'-0")
(Basement FloorF
Fly Ash Removal Equipment
Type
Design Efficiency, %
Scheduled Maintenance Shutdown
Interval, Months
Duration, Weeks
Table 9
Power Plant Input Data
Boiler No. 5
(3)
115
86
Boiler No.6
115(3)
7
86
Boiler No-. 7
115
(3)
6'-8'
120
boiler No.8
320
8'-6"
200
Mech. (May, 1975) Mech(May,1975) Mech(ESP May,1975) ESP
80 & 90
80
Varies
80
Varies
20-26(P8Ikt8g) 20-26 Peaking)
95
(1) Coal quality and heating value are average values for .coal burned in 1972.
(2) Operating data are at 100% load
(3) Units 5, 6, and 7 will be served by one new stack, 220' high.
-------
Muscatine
Plant
Table
10
Stack Gas Scrubbing System
Scrubbing System
No. Scrubbing Trains Required
Train Size(1)
Train Type
Wet Limestone
Wellman-Lord
Limestone System
Max. Design Capacity : tph
Wellman-Lord/Allied System
Sulfur Flow : Ib./hr.
Regeneration Area : No. Trains Required
Size
(2)
Purge/Make-up Area : No. Trains Required
Size
(2)
SO2 Reduction Area : No. Trains Required
Size
(2)
Boiler
No. 5, 6, 7
VII
9.0
3610
VI
VI
VI
(1) Refers to standard size scrubber modules.
(2) Refers to standard size modules.
Boiler
No.8
Boiler
No.
Boiler
No.
Boiler
No.
-------
Table 11
Power Plant Input Data
Riverside Plant
Iowa-Illinois Gas & Electric Company
General Plant Design Data
Plant Location
Plant Capacity, MW
No. of Boilers
No. of Generators
B ettendorf. Iowa
222
Coal Data
(1)
Source
Method of Transportation
Moisture, %
Ash, %
Sulfur, %
Heating Value, Btu/lb.
Illinois
Rail
16.8
8.7
2.6
10,420
Max. Monthly Avg. 2.9
Plant Operating Data in 1972
Plant Average Heat Rate, Btu/KWH_
Plant Average Load Factor, % 66 .2
12,671
161
-------
Riverside
Plant
Table 11
Boiler Data(2)
Turbo-Generating Capacity, MW
Coal Consumption, TPH
Air Flow
Total Air, SCFM
Excess Air, %
H
to Flue Gas Flow, ACFM
Flue Gas Temperature, °F
Boiler Efficiency, %
Total Hours Operation During 1972
Average Capacity Factor, %
year Boiler Placed in Service
Remaining Life of Unit, Yrs.
(based on 40 year life)
Related to Generator No.
Served by Stack No.
>wer Plant Input
Boiler No. 5
16
13.1
47,000
5
99,100
373
84.2
5,295
40.9
1937
3
3
5
Data
Boiler No. 6
20
14.8
52,000
5
103,000
375
83.8
7,419
54.4
1944
10
3
6
Boiler No, 7
22
14 '.4
51,000
5
91,000
300E8t
85.0
6,941
54.0
1949
15
4
9
Boiler No. 8
22
14.4
51,000
5
91,000
300 ESt
85.0
7,281
56.0
1949
15
4
9
-------
Riverside plant
Table 11
Power Plant Input Data
U>
Boiler Data*2*
Turbo-Generating Capacity, MW
Coal Consumption, TPH
Air Flow
Total Air, SCFM
Excess Air, %
Flue Gas Flow, ACFM
Flue Gas Temperature, °F
Boiler Efficiency, %
Total Hours Operation During 1972
Average Capacity Factor, %
Year Boiler Placed in Service
Remaining Life of Unit, Yrs.
(based on 40 year life)
Related to Generator No.
Served by Stack No.
Boiler No. 9
140
61.5
221,000
389,000
297
87.4
7,074
62.8
1961
27
Boiler No.
Boiler No.
Boiler No.
-------
Riverside plant
Table 11
Power Plant Input Data
Boiler Data(Cont'd) Boiler No.5 Boiler Mo.C Boiler No7 aoiler No.8
Stack Height, Ft. above grade 144 144 346 346
I.D. of Flue at Top, Ft. 8'-6" B'-6" 13'-4" 13'-4"
Distance to £ of Stack Breeching, Ft.
above grade (Grade = El 95'-6")
Fly Ash Removal Equipment
Type ESP ESP ESP ESP
Design Efficiency, 99.1 99.1 99.2 99.2
Scheduled Maintenance Shutdown
Interval, Months 12 - 14 12 - 14 12 - 14 12 - 14
Duration, Weeks 2-4 2-4 2-4 2 - A
(1) Coal quality and heating value are average'values for .coal burned in 1972,
(2) Operating data are at 100% load
-------
Riverside plant
Boiler Data(Cont'd)
Stack Height, Ft. above grade
I.D. of Flue at Top, Ft.
Distance to £ of Stack Breeching, Ft.
above grade
Fly Ash Removal Equipment
Type
Design Efficiency, %
Scheduled Maintenance Shutdown
Interval, Months
Duration, Weeks
Table 11
Power Plant Input Data
Boiler No.9 Boiler No.
346
Boiler No
Toiler No.
ESP
99.2
12 - 14
2-4
(1) Coal quality and heating value are average values for .coal burned in 1972.
(2) Operating data are at 100% load
-------
Riverside
Plant
Table 12
Stack Gas Scrubbing System
Boiler Boiler
Scrubbing System
No. Scrubbing Trains Required
Train Size(1)
Train Type
Wet Limestone
Wellman-Lord
No.5,6
1
V
No.7,8
1
Boiler
No .9
1
II
Boiler
No.
Boiler
No.
01
Limestone System
Max. Design Capacity
tph
Wellman-Lord/Allied System
Sulfur Flow : Ib./hr.
Regeneration Area : No. Trains Required
Size
(2)
Purge/Make-up Area : No. Trains Required
Size
(2)
S<>2 Reduction Area
: No. Trains Required
Size<2>
(1) Refers to standard size scrubber modules.
(2) Refers to standard size modules.
7020
III
IV
IV
-------
Table 13
Power Plant Input Data
Burlington Plan*-
Iowa-Southern Utilities Co.
General Plant Design Data
Plant Location
Plant Capacity, MW
No. of Boilers
No. of Generators
Burlington, Iowa
212
Coal Data
(1)
Source
Method of Transportation
Moisture, %
Ash, %
Sulfur, %
Heating Value, Btu/lb.
Illinois
Rail
20.5
8.2
2.6 Max. Monthly Avg. 3.O
10,136
Plant Operating Data in 1972
Plant Average Heat Rate, Btu/KWH 10,084
Plant Average Load Factor, % 59.2
167
-------
Burlington Plant
Table 13
Power Plant Input Data
CO
Boiler Data(2)
Turbo-Generating Capacity, MW
Coal Consumption, TPH
Air Flow
Total Air, SCFM
Excess Air, %
Flue Gas Flow, ACFM
Flue Gas Temperature, °F
Boiler Efficiency, %
Total Hours Operation During 1972
Average Capacity Factor, %
Year Boiler Placed in Service
Remaining Life of Unit, Vrs.
(based on 40 year life)
Related to Generator No.
Served by Stack No.
Boiler No. 1
212
89.2
348,000
20
644,000
261
86.4
8,180
59.2
1968
34
Boiler No.
Boiler No.
i*-»iler No.
-------
Burlington plant
vo
Boiler Data(Cont'd)
Stack Height, Ft. above grade
Z.D. of Flue at Top, Ft.
Distance to £ of Stack Breeching, Ft.
above grade
Fly Ash Removal Equipment
Type
Design Efficiency, %
Scheduled Maintenance Shutdown
Interval, Months
Duration, Weeks
Table 13
Power Plant Input Data
Boiler No. 1 Boiler No.
306
Boiler No.
P.iler No.
11' 9'
V1401
ESP
98.5
12
(1) Coal quality and heating value are average values for .coal burned in 1972.
(2) Operating data are at 100% load
-------
Burlington
Plant
Table
14
Stack Gas Scrubbing System
Boiler Boiler
Scrubbing System
No. Scrubbing Trains Required
Train Size{1)
Train Type
Wet Limestone
Wellman-Lord
No.l
III
No.
Boiler
No.
Boiler
No.
Boiler
No.
Limestone System
Max. Design Capacity :
tph
12.8
Wellman-Lord/Allied System
Sulfur Plow : Ib./hr.
Regeneration Area : No. Trains Required
Size
(2)
Purge/Make-up Area : No. Trains Required
.(2)
S02 Reduction Area
Size'
: No. Trains Required
Size<2>
5480
V
(1) Refers to standard size scrubber modules.
(2) Refers to standard size modules.
-------
Table 15
Power Plant Input Data
Kapp Plant
Interstate Power Company
General Plant Design Data
Plant Location
Plant Capacity, MW
No. of Boilers
No. of Generators
Clinton, Iowa
237
Coal Data
(1)
Source
Method of Transportation
Moisture, %
Ash, %
Sulfur, %
Heating Value, Btu/lb.
Illinois
Barge, Rail
11.8
11.0
3.1 Max. Monthly Avg.3.3
10,981
Plant Operating Data in 1972
Plant Average Heat Rate,
Plant Average Load Factor, %
10.465
59.8
171
-------
Kapp Plant
H
-J
NJ
Boiler Data
(2)
Turbo-Generating Capacity, MW
Coal Consumption, TPH
Air Flow
Total Air, SCFM
Excess Air, %
Flue Gas Flow, ACFH
Flue Gas Temperature, °F
Boiler Efficiency, %
Total Hours Operation During 1972
Average Capacity Factor, %
Year Boiler Placed in Service
Remaining Life of Unit, Yrs.
(based on 40 year life)
Related to Generator No.
Served by Stack No.
Table 15
>wer Plant Input
Boiler No. x
19
11.1
45,000
25
80,000
355
84.9
6406
52
1947
13
1
1
Data
Boiler No. 2
218
92
410,000
18
634,000
289
87.0
8070
71
1967
33
2
2
Boiler No.
Boiler No.
-------
Kapp
Plant
Boiler Data(Cont'd)
Stack Height, Ft. above grade
I.D. of Flue at Top, Ft.
Distance to ft of Stack Breeching, Ft.
above grade
Fly Ash Removal Equipment
Type
Design Efficiency, %
Scheduled Maintenance Shutdown
Interval, Months
Duration, Weeks
Table 15
Power Plant Input Data
Boiler No.i Boiler No. 2
210
25
None
(3)
245
13
37
ESP
98.0
Boiler No.
toiler No.
(1) Coal quality and heating value are average values for .coal burned in 1972.
(2) Operating data are at 100% load
(3) A new ESP for No.I will be on stream in early 1975.
-------
K*pp
Plant
Table
16
Scrubbing System
No. Scrubbing Trains Required
Train Size(1)
Train Type
Wet Limestone
Wellman-Lord
Stack Gas Scrubbing System
Boiler Boiler
No.l No.2
VIII
Boiler
No.
Boiler
No.
Boiler
No.
IV
Limestone System
Max. Design Capacity : tph
Wellman-Lord/Allied System
Sulfur Flow : Ib./hr.
Regeneration Area : No. Trains Required
Size<2>
Purge/Make-up Area : No. Trains Required
Size
(2)
S02 Reduction Area : No. Trains Required
Size
(2)
17.4
6780
III
IV
IV
(1) Refers to standard size scrubber modules.
(2) Refers to standard size modules.
-------
Table 17
Power Plant Input Data
Prairie Creek Plant
Iowa Electric Light & Power Co. &
Central Iowa Power Cooperative (Units 1,2,3)
General Plant Design Data
Plant Location
Plant Capacity, MW
No. of Boilers
No. of Generators
Cedar Rapids, Iowa
245
Coal Data
(1)
Source
Method of Transportation
Moisture, %
Ash, %
Sulfur, %
Heating Value, Btu/lb.
Illinois
Rail
16.9
8.5
2.5 Max. Monthly Avg. 3.1
10,473
Plant Operating Data in 1972
Plant Average Heat Rate, Btu/KWH
Plant Average Load Factor, %
11.031
53.5
175
-------
Prairie Creekpiant
Table 17
Boiler Data(2)
Turbo-Generating Capacity, MH
Coal Consumption, TPH
Air Flow
Total Air, SCFM
Excess Air, %
H
0^ Flue Gas Flow, ACFN
Flue Gas Temperature, °F
Boiler Efficiency, %
Total Hours Operation During 1972
Average Capacity Factor, %
Year Boiler Placed in Service
Remaining Life of Unit, Yrs.
(based on year life)
Related to Generator No.
Served by Stack No.
iwer Plant Input
Boiler No. 1
23.5
12.5
48,200
25
344
83
5,831
47.9
1950
16
1
1
Data
Boiler No. 2
23.5
12.5
48,200
25
344
83
5,970
51.1
1950
16
2
1
Boiler No. 3
49.5
25.5
104,200
22
183,000
313
85
8,010
60.8
1958
24
3
2
Boiler No. 4
149
62
266,600
20
448,000
284
87
7,388
59.4
1967
33
4
3
-------
Prairie Creek Plant
Boiler Data(Cont'd)
Stack Height, Ft. above grade
I.D. of Flue at Top, Ft.
Distance to ft of Stack Breeching, Ft.
above grade
Fly Ash Removal Equipment
Type
Design Efficiency, %
Scheduled Maintenance Shutdown
Interval, Months
Duration, Weeks
Table 17
Power Plant Input Data
Boiler No. 1 Boiler No. 2
180
180
16
16
80
80
Multiple Cyclones Multiple Cyclones
85 85
12
12
Boiler No-. 3
180
13
115
ESP
98.6
12
Boiler No.4
200
13
35
MCTA
(3)
80
12
(1) Coal quality and heating value are average values for .coal burned in 1972.
(2) Operating data are at 100% load
(3) A new ESP for Unit 4 will be on stream in October, 1974.
-------
Prairie Creek
Plant
Table 18
Scrubbing System
No. Scrubbing Trains Required
Train Size*1'
Train Type
Wet Limestone
Wellman-Lord
Stack Gaa Scrubbing System
Boiler Boiler
No.l. 2 No.3
IV
C
fmft^m
A
Boiler
No. 4
Boiler
No.
Boiler
No.
IV
H
-J
00
Limestone System
Max. Design Capacity : tph
18.7
Wellman-Lord/Allied System
Sulfur Flow : Ib./hr.
Regeneration Area : No. Trains Required
Size
(2)
Purge/Make-up Area
: No. Trains Required
Size<2)
SO? Reduction Area : No. Trains Required
Size<2>
6450
III
IV
IV
(1) Refers to standard size scrubber modules.
(2) Refers to standard size modules.
-------
Table 19
Power Plant Input Data
Sutherland Plant
Iowa Electric Light & Power Co.
General Plant Design Data
Plant Location
Plant Capacity, MW
No. of Boilers
No. of Generators
Marshalltown, Iowa
157
Coal Data
Source
(1)
Method of Transportation
Moisture, %
Ash, %
Sulfur, %
Heating Value, Btu/lb.
Rail
16.0
11.7
2.8 Max. Monthly Avg. 3.2
10,124
Plant Operating Data in 1972
Plant Average Heat Rate, Btu/KWH_
Plant Average Load Factor, %
11,470
73.5
179
-------
Sutherland plant
Table 19
00
o
Boiler Data(2)
Turbo-Generating Capacity, MW
Coal Consumption, TPH
Air Flow
Total Air, SCFM
Excess Air, %
Flue Gas Flow, ACFM
Flue Gas Temperature, °F
Boiler Efficiency, %
Total Hours Operation During 1972
Average.Capacity Factor, %
Year Boiler Placed in Service
Remaining Life of Unit, Yrs.
(based on 40 year life)
Related to Generator No.
Served by Stack No.
»wer Plant Input
Boiler No. 1
37.5
21
76,500
22
137,000
325
85
8,424
76.6
1955
21
1
1
Data
Boiler No. 2
37.5
21
76,500
22
137,000
325
85
7,920
71. 5
1955
21
2
2
Boiler No. 3 Boiler No.
81.6
42
160,000
16
269,000
335
88
7,752
81.4
1961
27
3
3
-------
Sutherland plant
Table 19
CO
Boiler Data(Cont'd)
Stack Height, Ft. above grade
I.D. of Flue at Top, Ft.
Distance to £ of Stack Breeching, Ft.
above grade
Fly Ash Removal Equipment
Type
Design Efficiency, %
Scheduled Maintenance Shutdown
Interval, Months
Duration, Weeks
Power Plant
Boiler NoJ.
190
81
133'
MCTA
80
12
3
Input Data
Boiler No. 2
190
81
133'
MCTA
80
12
3
Boiler, No. 3
190
10'-6"
156'
MCTA
80
12
Boiler No.
(1) Coal quality and heating value are average values for .coal burned in 1972.
(2) Operating data are at 100% load
(3) New ESP's are being installed on all boilers by early 1975.
-------
Sutherland
Plant
Table
20
Scrubbing System
No. Scrubbing Trains Required
Train Size(1)
Train Type
Wet Limestone
wellman-Lord
Stack Gas Scrubbing System
Boiler Boiler
No.l No.2
A
A
VI
Boiler
No.3
i
tv
Boiler
No.
Boiler
No.
CO
to
Limestone System
Max. Design Capacity : tph 13.3
Wellman-Lord/Allied System
Sulfur Flow : Ib./hr. 4980
Regeneration Area : No. Trains Required 1_
Size
(2)
Purge/Make-up Area : No. Trains Required
Size
(2)
S<>2 Reduction Area
: No. Trains Required
Size<2>
(1) Refers to standard size scrubber modules.
(2) Refers to standard size modules.
-------
APPENDIX B
WET LIMESTONE SYSTEM
183
-------
B
DAT! .T CM.
''
\ 84
DMAWMl 9fc,
THE M W KELLOGG COMPANY
> Pmm« KCOtFOtATIO
-------
^ AX»OX*7
< rt/vfj? wtr-ffr
B
11X17
185
PAMICATIOM
IIMIUKD
C...T.
THE M W. KELLOGG COMPANY
Ncotfoum
FIG,
-------
r-- .
[UEUOCO]
\W/
Table 21
EQUIPMENT LIST
CLIEMT: EPA-Iowa Utilities Study
JOB/EST. NO.
LOCATIOK:
TYPE UNIT; Limestone System; Area-
CLASS F.J.K.L
PAGE NO.; 1 OF
ITEM
NO.
101-F
102-F
103-F
104-F .
101-J
10 2 -J
103-J
104-J
105-J
106-J
101-K
101-L
102 -L
DESCRIPTION
EQUIPMENT TYPE: F-Drums a.nd Tanks
Unloading Hopper
Live Storage Silos
Limestone Slurry Storage TanK
Ef.fluent Slurry Surge Tank
J-Pumps and Drivers
Limestone Slurry Feed Pumps
Raw Water Pumps
Pond Water Recycle Pumps
Effluent Slurry Surge Tank Pumps
Entrainment Separator Pumps
Wash Water Pumps
K-Buildings
Grinding Building
L-Special Equipment
Ball Mills (Incl. weigh feeder, mill, classifiers, slurry
sump, slurry pumps)
Thickener (If required)
&
"5~
u
3c
in z
CHECKS IN FAR RIGHT HAND COLUMN INDICATE ITEMS CHANCED IN LATEST ISSUE.
STANDARD DISTRIBUTION (ENTIRE EQUIPMENT LIST)
DIV. OR SECT.
DESIGN
(ft
y
k
«
>
M
Slrm
CMB3T
V&SVRbl1-
&K.ORT,
Rim&MCNT
M&VV
fihWvUfM
SYSTEMS ENC.
IMS^I'UMCNT
LOUICMCNT
ATTENTION OF.
DIV. OR SECT.
ifi
>IU
5S
lTAtWffD>
CIVIL CMC.
WWtiVv-.
yabrtwi-*1-
uwtw*
IEM*WWMC
H
»
i
HOME OFFICE
FILLO
COST SEHVICES
pnocEki Men.
ATTENTION OF:
ADDITIONAL DISTRI3.THIS SHEET ONLY
DIV. OR SECT.
S^BSS'""'6
ATTENTION OF
186
ISSUE NO.
DATE
1
2
3
4
5
G
7
a
9
10 1 U
1
12
-------
EMC rnoj »-io
LOCATION:
EQUIPMENT LIST
EPA - Tnwa Utilities ^nfly
JOB/EST.
UPE UNIT: Eimestone System; Rxea 100
CLASS V.
PAGE NO.: 2
OF
ITEM
NO.
-V
102 -V
10 3 -V
10 4 -V
105 -V
DESCRIPTION
EQUIPMENT TYPE: V-Transportation Equip.
feeder '
Tunnel Belt Conveyor
Stacker
>lant Conveyor
Tripper Belt
3 LJ
5 fcs
"ft""
u
2o
M 2
CHECKS IN FAR RIGHT HAND COLUMN INDICATE ITEMS CHANGED IN LATEST ISSUE.
STANDARD DISTRIBUTION (ENTIRE EQUIPMENT LIST)
DESIGN
a
K
fl
X
M
. OR SECT.
ok%V&&
PL AM T
LAYOUT
Kgi^aiA.1-
&%V0RTS
frlslitlMCMT
WfiflV
h)»S?»oWi-i*f
ivlTCMl LNC.
'r'Wc'."11'-11"1
tsv.:f "" T
OIV. O« SECT.
1
:?6
>u
0s
iWifttf0*
CIVIL CNG.
t 1CM. C-IV.
Vfcb'.'tiO.1-111-
WIVMilf10
i£«W7«NS
j}
HOMC OPFICC
HLI.U
COST irnvictf
pnoccssMCH.
ATTENTION OF:
DIV. OR SECT.
SUBBM**"4
ATTENTION Of-
1-87
(issue M o.
OATF
1
2 1 3
1
4
S
6 .
7
a
9
10
1 1
l
-------
CMC PHOJ » 9-70
EQUIPMENT LIST
CLIENT: EPA - Iowa, Utilities Study
JOB/EST. HO. 41*1-8-03-
LOCATION: _
TVPE Ull IT; Scrubbing JErain ;
Area 200
CLASS
PAGE HO.:
C.E.F.G.
OF
ITEM
NO.
201-C
201-E
202-E
201-F
202-F
201-G
»
DESCRIPTION
EQUIPMENT TYPE: OHeat Exchanqers
Reheater
E- Towers
Venturi Scrubber
TCA Absorber
F-Drums and Tanks
Vent. Scr- Circulating Tank
Absorber Circulating Tank
G-Separators
Sntrainment Separator
38-
H gS
~5
bl
rfc
iC.
tnV.'10 JtllT
[&H!""EN T
ATTENTION OF
OIV. OR SECT.
;S
G2
iT/k5yy5^°s
CIVIL CNC.
WC'M*?.TV.
trit. ofV.*-"1-
h?iW*ESNC
ifctH-rWi"10
J;
§
HOVir OFFICE
HltLD
COal SLRviCEI
PROCESS MflH.
ATTENTION OF:
ADDITIONAL DISTRI3. THIS SHEET ONLY
DIV. OR SECT.
»yicSV*s'NC
ATTENTION O*
188
1 issue NO.
OATC
1
2
3
4
>
6 I 7
1
a
9
IO
1 1
1?
-------
CMC PROJ 0 »-»0
w-.
ucuucn
\w/
EQUIPMENT LIST
CLIEKT: . EPA - Iowa Utilities Study
JOB/EST. HO.4118"03
LOCATION:
TYPE UNIT; Scrubbing Train; Area 2QO
CLASS J,L,M
PAGE NO.; 4
OF
ITEM
NO.
201-J
202-J
203-J
201-L-
202-L
203-L
204-L
205-L
201-M
202-M
203-M
204-M
205-M
206-M
207-M
208-M
DESCRIPTION
EQUIPMENT TYPE: J-Pumps, Blowers , Drivers
Vent. Scr. Circulating ^wips
Absorber Circulating Pumps
Forced Draft Fan
L-Special Eauipment
Vent. Scr. Tank Aaitator W/Motor
Absorber Tank Agitator W/Motor
Soot Blower (Inlet Duct to Venturi)
Soot Blower (Elbow to Ent. Separator)
Soot Blower (Reheater)
M-Piping
Duct To Fan
Duct From Fan To Vent. Scr.
Duct From Ent. Sep. To Reheater
Duct From Reheater To Stack Duct
Inlet Shut-Off Gate
Outlet Shut-Off Gate
Bypass Shut-Off Gate
Duct From Abs. To Ent. Separator
ifs
I*.1
SC-
OT z
CHECKS IN FAR RIGHT HAND COLUMN INDICATE ITEMS CHANGED IN LATEST ISSUE.
STANDARD DISTRIBUTION (ENTIRE EQUIPMENT LIST)
OIV. OR SECT.
o
«n
O
CMSAf Atl
DCIICN
LAYOUT
?ON?Sb*J-
JUP^ORTJ
GJsW&MENT
MfiRV
fihSfcuWWf
SYITCMS INC.
cVc.fi ""*"'
LQUIPMCNT
ATTENTION OF
DIV. OR SECT.
§
U
r^syfes?0*
CIVIL CNG.
WiWWv.
eaG^Bi^^"1-
f^H\!1cJlN°
ifHtf^s'NC
5
ft
MOMC OFFICE
FIELD
COST SENVICES
PROCESS MCR.
ATTENTION OF:
ADDITIONAL DISTRIB. THIS SHEET ONLV
DIV. OR SECT.
PVJB6V**'NC
ATTENTION OF
189
1 ISSUE NO. I 1
DATE 1
2
3
4
5
6
7
8
9
IO
II
12
-------
190
95'
30'
-40'-
-JS-
--^
J":--"i
il-ia-r^i-t
hi
4
A
, -
!" J
)'
- r
i
i
I-~-'
I
1
~3
-^
^;
1
1 \
' /
f|3
n^"?*^''
Sj
1^1 I"
.-4.Lri4
- J.
*' PXllLMAN IMCO'POIATID
FIG, 7
-------
B
HKVIB10N DB0CHIPTI
191
I t*«UID FOM
| CONSTRUCTIO
OUAWM yyx^o
3:
THE M. W KELLOGG COMPANY
a 4l*M
-------
c :
NO. HIVIBION I
IISVUCD FOR
coMvrnucTK
THE M.W. KKLLOOaCOMPANY
CLAM AMKA
192
-------
Table 22
ABSORBER-VENTURI STANDARD SIZES
VIH
ACfM W.I 1 12SV175*
ACFM Rot 1 100*
sent (Rot)
Hot Duot/Stadt Duet
Nominal N.w.
Paetor
A3SORBIK
i/ci CPH/Mscm
ON Total
Slsa
NO. PIUIBI
IIP t 6J% Bff. (TOt.)
Ho tarn Ha. /Bp Ba.
MS. TAMX
Gal.
DlMn.
r«i BII? 65« err.
VtMTUni
L/Cl GFM/KSCFM
CPH Total
Slia
Ho. Pimpa
BMP t «S% til. (Tot.)
Motorat Ho./Rp Ba.
VCTTURI TA1K
Gal.
Olmn.
BEMtMtRl qi MBTO/H
*0i Ft*/»til
DlMni Rt/Width/Dlpth
Bo. Tuboa/Dla. /length
Bo. Bova Hlgh/Daop
4SO, 000/481 .606
545,000
171,000
l!>xl2>/12'Bll'
112
1.080
64.1
24,000
IS' x 40'
1 (1 + SP.)
144
J/SOfl
141,000
40' 0 B 15*
1100
16.1
6000
2 11 * BP.)
211
2/250
15.100
20' 0 B 15*
21.9 .
14.140/60,000
IS' B 14* B 43*
4060/1V141
116/15
H
1*4.068/411,000
477,066
126,000
12'xir/irBll'
IS*
0.875
64. S
21,001
IS' x 33'
1 (2* SP.)
Ill
1/488
111,880
17* 0 B «'
26*0
16.1
S2SO
2 (1 » SP.)
201.5
2/150
10,900
19' 0 B 15'
20.9
1), 070/51, SOO
14' x 11' B 41*
11SO/1V111
116/15
...»F',.
118,680/167,000
401,000
288,000
ll'xll'/lO'BlO*
111
8.750
14. S
10,000
IS' x SO'
1 (2 + SP.)
Ill
1/408
106 ,000
IS' 0 B IS*
2475
16.1
4560
2 (1 + SP.)
174
2/206
26,500
17' 0 x 15*
17.9
11,200/45,000
11' x 12' B 45*
1S70/1V121
102/15
AV
111.606/101,000
141,646
111,006
lO'xlO'/U'B*'
114
0.621
64.5
IS. 000
15' B 25'
1 (2 * SP.)
517
V100
08,100
32' 0 B IS'
2060
16.1
3710
1 11 * SP.)
145
2/1S4
12.100
11' 0 B 11'
14.9
9,340/17,300
12' x 11' x 45"
12SS/1V111
91/15
125,000/244,000
271,000
167,000
»«»/»'«*'
91
0.500
64.5
12 .000
IS' B 20'
1 (2 * SP.)
422
I/ISO
70. SOO
28* 0 B IS'
1656
16.1
3006
1 (1 + SP.)
Ill
1/125
17.700
14' 0 B IS'
11.9
7,470/30,000
11' B 10' B 43*
2070/1 V10'
11/15
16* .000/113 .000
204.000
148 .000
O'xS'/OW
61
.375
64.5
(.000
15' S 15*
3 (1 » SP.)
116
1/175
51 ,960
25' 0 B IS'
1140
16.1
22SO
2 (1 « SP.)
87
1/100
11,100
11--6- 0 IS'
9.0
5,600/21,500
*' B 10' B 45*
1110/lVlO'
41/15
««^^M«
112.500/122,000
116.000
91,100
71»6'/6'x6'
41.5
0.15
64.5
(.000
15 'BlO*
1 (1 SP.)
Ill
I/US
35,300
20' 0 B IS!
135
16.1
1500
2 (1 * SP.)
S7.1
1/75
0810
11' 0 B IS'
6.0
1, 740/15.000
7' B 8' B 45*
1785/1V6'
51/15
75.000/11,100
0.900
61.100
S'BS'/S'xS'
M.l
<.1»7
64.5
4.000
1S-B6.67-
1 (i » sr.»
141
1/75
23.300
14--4- 0 x 13'
550
16.1
1000
1 (1 » SP.)
11. S
1/50
5810
S' 0 8 IS*
4.0
1.410/10.000
( 7* 45*
1165/1V7'
19/13
-------
Table 23
WET LIMESTONE PROCESS
STANDARD SIZES
Scrubber Area Dimensions: Ft. (Width x Length)
SIZE I II III IV V VI VII VIII
Type A 60 x 140 56 x 136 52 x 132 48 x 128 44 x 124 40 x 120 36 x 116 32 x 112
Type B 60 x 196 56 x 190 52 x 184 48 x 178 44 x 172 40 x 165 36 x 159 32 x 153
Type C 60 x 65 56 x 61 52 x 57 48 x 53 44 x 49 40 x 45 36 x 41 32 x 37
Notes: Type A has fan at grade (HT = 95')
Type B has fan at grade with additional pumps (HT =85')
Type C has fan over venturi scrubber (HT =95')
-------
PAGE NOT
AVAILABLE
DIGITALLY
-------
Tatele 24
SLURRY POND
150 CY/H FOR A 550 MW'PLANT BURNING 4.3% SULFUR COAI,
150% STOIC. QUANTITY; SLUDGE IS 40% SOLIDS
70% LOAD FACTOR (6132 HR/YR)
NUMBER YEARS STORAGE
PLANT SIZE: MW
5 YRS
10 YRS
15 YRS
20 YRS
25 YRS
200
400
1.67 MMCY 3.3 MMCY 5.02 MMCY 6.69 MMCY 8.36 MMCY
(20.7) (41.5) (62.2) (82.9) (103.6)
3.34 MMCY 6.70 MMCY 10.04 MMCY 13.38 MMCY 16.72 MMCY
(41.4) (83.1) (124.5) (165.9) (207.3)
600
5.01 MMCY 10.05 MMCY 15.06 MMCY 20.07 MMCY 25.08 MMCY
(62.1) (124.6) (186.7) (248.8) (310.9)
800
6.68 MMCY 13.40 MMCY 20.08 MMCY 26.76 MMCY 33.44 MMCY
(82.8) (166.1) (248.9) (331.7) (414.5)
1000
8.35 MMCY 16.75 MMCY 25.10 MMCY 33.45 MMCY 41.80 MMCY
(103.5) (207.6) (311.2) (414.7) (518.2)
Sample Calculation:
Calculate the pond size (50 feet deep) required for a
1180 MW power plant burning 3.2% sulfur coal with a load
factor of 60% to hold 20 yrs. stg.
Area = Area, nrtn (Gen. Cap.) (Fraction Sulfur) (Load Factor)
1000 Ratio Ratio Ratio
Area = 414.7 x
x
= 312 Acres
No. in parentheses ( ) = No. of acres of pond 50' deep
196
-------
PAGE NOT
AVAILABLE
DIGITALLY
-------
APPENDIX C
WELLMAN-LORD/ALLIED SYSTEM
205
-------
PAGE NOT
AVAILABLE
DIGITALLY
-------
KM a PNOJ B-TO
Table 25
EQUIPMENT LIST
CLIENT: EPA - Iowa Utilities Study
LOCATI on; Wellman-Lord/Allied Process
JOB/EST. HO. 4118-03
CLASS C,E,F,J
TYPE UHlTScrubbing Train; Area 100
PAGE NO.: 1
OF
ITEM
NO.
101-C
101-E
101-F
101-J
102-J
103-J
104-J
t
DESCRIPTION
EQUIPMENT TYPE: C-Heat Exchangers
Reheater
E-Towers
Absorber
F-Drums & Tanks
Absorber Surge Tank
J-Pumps, Compressors, Blowers, Drivers
Booster Fan
Quench Pumps
Prescrubber Circ. Pumps
Absorber Circ. Pumps
ijs
it
CHECKS IN FAR RIGHT HAND COLUMN INDICATE ITEMS CHANGED IN LATEST ISSUE.
STANDARD DISTRIBUTION (ENTIRE EQUIPMENT LIST)
DESIGN
u
t-
M
BEY**,
CkflSur
5!fiS₯8b\u
SIWORTS
BlSVUftMBNT
PoWR*
fiMWiE/feff
SYSTEMS CMC.
ISK!PMEMT
,
d6
0s
1 SPECS.
CIVIL ENG.
WcWfefv.
esfc. erv.-"1-
fSSW^ZsNC
iEH
1
vfc'W*
HOME OFFICE
PICLO
COST SERVICES
PROCESS MCR.
ATTENTION OF:
ADDITIONAL OISTRIB. THIS SHEET ONLY
DIV. OR SECT.
SyiST1**""5
ATTENTION OF:
20&
DATE
1
2
3
4
S
6
7
8
9
to
-rrn
J
-------
N« PMOJ -10
EQUIPMENT LIST
JOB/EST. HO..
CLIENT:
LOCATION:
TYPE UN IT: Regeneration Section: Area 200
CLASS C,E,F,J
PAGE NO.: 2
.OF
ITEM
NO.
201-C
202-C
203-C
204-C
205-C
201-E
201-F
202-F
203-F
204-F
201-J
202-J
203-J
204-.J
205-J
206-J
207-J
208-J
209-J
210-J
DESCRIPTION
EQUIPMENT TYPE: C-Exchangers & Condensers
Evaporater Heater
Primary Condenser
Secondary Condenser
S02 Superheater
Condensate Cooler
E- Towers
Condensate Stripper
F-Drums & Tanks
Evaporator Feed Tank
Evaporator
Dump/Dissolving Tank
Absorber Feed Tank
J -Pumps , Compressors, Blowers, & Drivers
Filter Feed Pumps
Flyash Filter Sump Pumps
Evaporator Feed Pumps
Evaporator Condensate Pumps
Evaporator Circulating^Pump
Mother Liquor Pumps
Transfer Pumps
Absorber Feed Pumps
Condensate Stripper Pumps
SC>2 Compressor
lls
i«
CHECKS IN FAR RIGHT HAND COLUMN INDICATE ITEMS CHANGED IN LATEST ISSUE.
STANDARD DISTRIBUTION (ENTIRE EQUIPMENT LIST)
DIV. OR SECT.
DESIGN
ii
M
\-
>
n
EUVfeft
CWojT
Vd£₯Blft!-
EWOIITI
fiirvfcWNT
fcUttkV
&Wr«,E/Wf
SYSTEMS CNC.
UJflTHUMSNT
I8H!PMMT
ATTENTION OF:
DIV. OR SECT.
I
J6
cX
> u
fi*
r&\Bfgoa
CIVIL EMC.
^tWWSfv.
w&rBrv.1-"1-
ni5vic-isNC
8EHvRHWNC
^
J_
HOME OFFICE
FIELD
COST SERVICES
PROCESS MGR.
ATTENTION OF:
ADDITIONAL DISTRIB.THIS SHEET ONLY
DIV. OR SECT.
SUi&T"""""
ATTENTION OF:
209
ISSUE NO.
I ' I ' I ' I ' I ' I ' I 7 I ' I ' I
ie
DATE
-------
NO PMOJ« »-»C
EQUIPMENT LIST
JOB/EST. NO..
CLIENT:
LOCATION:
TYPE UNIT:
ITEM
NO.
201-L
CLASS L
Area 200 (Cont.) PAGE NO.: 3 OF
DESCRIPTION
EQUIPMENT TYPE: L-Special Equipment
Flyash Filters
6
BD
-is
n o
In z
1
CHECKS IN FAR RIGHT HAND COLUMN INDICATE ITEMS CHANGED IN LATEST ISSUE.
STANDARD DISTRIBUTION (ENTIRE EQUIPMENT LIST)
DESIGN
M
EBsYifc
Ckv-BuT
WfiffBoV-
si^ORTS
RIHWMMT
pbWw*
fiJsSWB/fiff
SYSTEMS CMC.
K1W."UMItMT
18V! M«HT
1
>u
1 SPECS.
CIVIL EN6.
KWtfefv.
ESfc. 6fV.V u
!iH
0
1
IRJtofNG
HOME OFFICE
PROCESS MGR.
DIV. OR SECT.
gmgLjAiilMe
ATTENTION OF:
210
DATE
1
2
3
4
Z
6
7
8
9
1O
11
-5-1
..,!
-------
IKEUOOOI
CMC PMOJ 9-TO
EQUIPMENT LIST
CLIENT:
LOCATION:
TYPE UNIT: Purge/Make-Up Section: Area 300
JOB/EST. NO..
CLASS Lz
PAGE NO.:
OF
ITEM
NO.
106-F
307-P
308-P
310-J
DESCRIPTION
EQUIPMENT TYPE: F-Drums & Tanks
Purge Solids Bin
Na0 CO- Bin
Na; CO, Mix Tank
- 3
J- Pumps, Compressors, Blowers, & Drivers
Na,, CO., Pumps
2 3
-fS
Ul
I*
CHECKS IN FAR RIGHT HAND COLUMN INDICATE ITEMS CHANGED IN LATEST ISSUE.
STANDARD DISTRIBUTION (ENTIRE EQUIPMENT LIST)
DIV. OR SECT.
DESIGN
3
u
H
1
>
M
olfs'i'ifc
Ek«8iT
₯6S?HA.L
SU^ORTS
RJ?W,?1MENT
k>b%TR'
Rh^taWf
SVSTEMS ENG.
|U1
nz
rsVtav?05
CIVIL EN6.
Gftftttfv.
TSfifcrerv.""1-
fl5We2lNG
iiH5fyfe'NC
~?
s
HOME OFFICE
FIELD
COST SERVICES
PROCESS MGR.
ATTENTION OF.
ADDITIONAL DISTRIB. THIS SHEET ONLY
DIV. OR SECT.
pyggljIASING
ATTENTION OF
211
{ISSUE NO.
DATE
1
2
3
4
5
6
7
a
9
10
11
12 1
J
-------
KN« PMOJ t-70
EQUIPMENT LIST
CLIEHT:
LOCATION:.
TYPE UNIT:
JOB/EST. NO..
CLASS.
B
SO., Reduction:
400
PAGE NO.;
.OF
ITEM
NO.
401-B
DESCRIPTION
EQUIPMENT TYPE: B-Furnaces, Fired Heaters & Stacks
Tail Gas Incinerator
SB
.is
§o
z
CHECKS IN FAR RIGHT HAND COLUMN INDICATE ITEMS CHANGED IN LATEST ISSUE.
STANDARD DISTRIBUTION (ENTIRE EQUIPMENT LIST)
DESIGN
ISVSTCMI
BtfsYifc
Ekv-SilT
₯&3?BIA.L
SOP^ORTS
Rim&l«IT
WUkV
ftMUMfiN-
SYSTEMS ENC.
I^IPMENT
DIV. OR SECT.
-S
>UI
n1
rsVttft*os
CIVIL ENC.
^VfAVN:
e'SfcrBI'v'"*'
&wtir°
SERfftfW"5
HOME OFFICE
FIELD
COST SERVICES
PROCESS M6R.
ATTENTION OF:
ADDITIONAL DISTRIB.THIS SHEET ONLY
OIV. OR SECT.
gyRjftA*M<
ATTENTION OF:
212
1 ISSUE NO.
DATE
1
2
3
4
5 I 6
1
7
8
9
10
11
12 |
J
-------
lUUOMl
NO FHOJ 9-10
CLIENT:
LOCATION:
TYPE UNIT:
EQUIPMENT LIST
JOB/EST. HO.
CLASS C.D.F.G.J
S00 Reduction;
400 (Cont.)
PAGE NO.:
.OF
ITEM
NO.
403-C
404-C
405-C
406-C
407-C
401-D
402-D
403-D
404-D
401-F
401-G
402-J
403-J
404-J
405-J
DESCRIPTION
EQUIPMENT TYPE: C-Exchangers & Condensers
Feed Preheater
Mixed Gas Cooler
1st Sulfur Condenser
2nd Sulfur Condenser
3rd Sulfur Condenser
D-Converters, Reactors, & Regenerators
Heat Regenerators
Reduction Reactor
1st Claus Reactor
2nd Claus Reactor
F-Drums & Tanks
Sulfur Pit
G-Separators
Tail Gas Mist Eliminator
j-Pumps, Compressors, Blowers, & Drivers
Sulfur Pit Pumps
Dilution Air Blowers
Combustion Air Blowers
Start-up Air Blower
ffi
_K
Si
CHECKS IN FAR RIGHT HAND COLUMN INDICATE ITEMS CHANGED IN LATEST ISSUE.
STANDARD DISTRIBUTION (ENTIRE EQUIPMENT LIST)
OIV. OR SECT.
in
U
0
[SYSTEMS
EtfsVifc
Ekv-oST
c'oSTlbV-
WONTI
RlfVfc&MENT
pBttkV
KMtUGttttf
SYSTEM* ENC.
flJJRUMENY
IgglPMENT
ATTENTION OF:
DIV. OR SECT.
ib
>iii
nz
rsW&i1?05
CIVIL ENC.
W₯W%TV.
wtrBrvj""1-
Hxvf^zir10
!EH5RHWNG
HOME OFFICE
FIELD
COST SCNVICES
PROCESS MOB.
ATTENTION OF:
ADDITIONAL OISTRIB. THIS SHEET ONLY
DIV. OR SECT.
SHIST-**"0
ATTENTION OF:
213
ISSUE NO.
10
II
DATE
-------
FROM BOILER.
IQI-C
J
~7
101-E
IQI-F
fin fin nil II HIM
i
QUENCH PrCSCKUBftte A3SORSER.
PUMPS FfcN ClRC. POMP* CltlC PUMPS
IO2.-T IQI-T 10^-T 104-T
UO' -- - i
PLAN
SIZE i
7
y'
o
fcBSORBK.
<7
i ' i I" "I n n n
4fc
n n n n
35-
ELEVAJTION
A560RBEK
n n r
-24
SIDE VIEW
TYP A .
\NELLMAN-LIKD PROCESS
B
214
DESCRIPTION
DAT! «T CHK
THE M. W. KELLOGG COMPANY
»f PUU-MAN IMCOIW(MATO
100
4118-03
OAT1D: fc-5-74
MODULE
V6 2!
DKAWIN4 NO
-------
I
fcl'
REGENERATION : AREA 200
nn
SIZE m
201-C
Q
nn
SOZ REDUCTION: AREA, 400
ooo
40.-.* 40Z-P
&
PURG,^/ MA^E-UP: AREA 300
SIZE U
ZH
»i )
^~^
510-T
cz) cm
PKOCCS&
^15
MEVICION DIMCMIPTIOM
i«u: i-.jo1
MVWK: DOM
THE M. W. KELLOGG COMPANY
A mlHH * PUULJftAN IMCOHVOOATYD
2B0.3DP
-- --
DATKD: 5-15-74
Fl(^. 22
[MIAWIN4 NO
-------
Table 26
WELLMAN-LORD/ALLIED PROCESS
STANDARD SIZES
Scrubber Area
Size
ACFM '@
Factor
Dimen.
300°F
: Ft.
I
545,
1.
000
0
60x140
II
477,000
0.875
56x136
III
409,000
0.750
52x132
IV
341,000
0.625
48x128
V
273,
0.
000
500
44x124
VI
204,000
0.375
40x120
VII
136,000
0.250
t
36x116
VIII
90,900
0.167
32x112
Regen. Area
Size
Sulfur
Factor
Dimen.
to
Flow: Ib/HR
: Ft.
I
9,
1.
000
000
69x191
II
8,000
0.889
65x184
III
7,000
0.778
61x177
IV
6 ,000
0.667
57x170
V
5,
0.
000
555
53x163
VI
4,000
0.444
49x156
VII
3,000
0.333
45x149
VIII
2,000
0.222
41x142
H Purge/Make -Up Area
Size
Sulfur
Factor
Dimen .
Flow: Ib/HR
: Ft.
I
18,
1.
000
000
94x223
II
14,000
0.778
82x211
III
10,000
0.555
70x199
IV
7,000
0.389
61x190
V
5,
0.
000
278
55x184
VI
4,000
0.222
52x181
VII
3,000
0.167
49x178
VIII
2,000
0.111
46x175
SO0 Reduction Area
Size
Sulfur
Factor
Dimen.
I
Flow: Ib/HR
: Ft.
18,
1.
000
000
66x143
II
14,000
0.778
58x127
III
10,000
0.555
50x111
IV
7,000
0.389
44x99
V
5,000
0.278
"0x91
VI
4,000
0.222
3Rx87
VII
3,000
0.167
36x83
VIII
2,000
0.111
34x79
-------
N
-------
APPENDIX D
COAL CLEANING SYSTEM
225
-------
LEGEND
_^_^ CWL
RCFUSE
SLURRIES
CONCCNTRATEO MAGKETITC
Oil U1F MAGNETITE
. _ ClARiriCD OXER
SEE REF 2., Pit
-------
REllOBBl
ENC PROJ 6 9-10
Table 27
EQUIPMENT LIST (Incomplete - not a11 PumPs>
conveyors, sumps, etc. shown)
JDB/EST. NO. miB-03
EPA - Iowa Utilities Study
LOCATION; Iowa - CLASS B. F. G
CLIENT:
TYPE UNIT; Coal Cleaning Plant
PAGE NO.:
OF
ITEM
NO.
101-B
101-F
102-P
103-F
104-F
105-F
106-F
107-F
108-F
101-G
102-G
10^-G
104-G
10R-G
106-G
107-G
108-G
109-G
110-G
111-G
112 G
113-G
114-G
115-G
116-G
n7-fi
118-G
DESCRIPTION
EQUIPMENT TYPE: B__Furnaces Fired Hea-ters , & Stacks
Thermal Dryer (Alternate)
F - Drums and Tanks
Raw Coal Receiving Bin
Raw Coal Silo
Pulp Sump
Heavy Media Sump (Fine Coal Treatment)
Heavy Media Sump (Coarse Coal Treatment)
Refuse Bin
Clean Coal Silo
Water Tank
G - Separators
Raw Coal Screen
Pre-Wet Screen
Sieve Bend Screen
Deslimine Screen
Heavy Media Cyclone (Fines}
Refuse Drain and Rinse Screen
Second Sieve Bend Screen
21ean Coal Drain and Rinse Screen (Fines)
Magnetic Separator (Fines)
Centrifugal Dryer
ieavy Media Washer
Refuse Drain and Rinse Screen (Coarse)
^lean Coal Drain and Rinse Screen (Coarse)
Centrifugal Drver (Coarse)
Magnetic Separator (Coarse)'
Classifying Cyclones
?rnhh Cells
]lean Coal Filter
z w
?«s
0? o
M Z
CHECKS IN FAR RIGHT HAND COLUMN INDICATE ITEMS CHANGED IN LATEST ISSUE.
STANDARD DISTRIBUTION (ENTIRE EQUIPMENT LIST)
DIV. OR SECT.
DESIGN
U
t-
n
>
M
oHvftfc
LkCSiT
₯&5?BIAL
flllWoRTS
RJ?W.WNT
w&tv
fiWrfcLBWf
SYSTEMS ENC.
EtfJ.RUMENT
IJjylPMENT
ATTENTION OF
DIV. OR SECT.
I
=16
> u
nz
TsWA?05
CIVIU ENC.
'k'i'c'W'bfv-.
ififcrsru;-"1-
fiS
-------
EMC PROJ 6 8-70
EQUIPMENT LIST
JOB/EST. NO..
CLIENT:
LOCATIOM:_
TYPE DM IT:
CLASS G. Jf Kr L
PAGE HO.t ? OF 2
ITEM
NO.
119-G
101-J
102-J
101-K
101-L
102-L
DESCRIPTION
EQUIPMENT TYPE: G - Separators (Cont.).
Refuse Filter
J - Pumps, Compressors, Drivers
Heavy Media Pumps (Fines)
Heavv Media Pumps (Coarse)
K - Buildings
Preparation Plant Building
L - Special Equipment
Coal Crusher
Thickener
-fS
u
3d
z
CHECKS IN FAR RIGHT HAND COLUMN INDICATE ITEMS CHANGED IN LATEST ISSUE.
STANDARD DISTRIBUTION (ENTIRE EQUIPMENT LIST)
DIV. OR SECT.
DESIGN
SYSTEMS
DE°sY&£l
Ekv-SiT
«&5fBb"Ll-
SUPPORTS
RJfn&MENT
WStkV
Ws^.I.M'.FN**-
SYSTEMS CNG.
INSTRUMENT
igy.PMENT
ATTENTION OF.
DIV. OR SECT.
d6
>ID
n5
r/pVA?08
CIVIL ENC.
HMWfcfv.
iRfcreru.*-"1-
flSWESN6
iiH^fyteING
^!
g
HOME OFFICE
FIELD
COST SERVICES
PROCESS MCR.
228
ATTENTION OF'
ADDITIONAL DISTRIB. THIS SHEET ONLY
DIV. OR SECT.
PUJC^ASING
ATTENTION OF
ISSUE NO.
DATE
1
2
3
4
5
6
7
e
9
10
1 1
12
-------
RAW COAL
RECEIVING
BIN
o
a
tm -
ui
cc
oc
o
j
EMERGENCY
PONDS
QC
O
UJ
O
O
CONVEYOR
15,000 TON
CLKAN COAL
SILO
THirifFWPR
THICKENCR
PREPARATION
PLANT
1500 TON
RAW COAL
SITE
i 1
POSSIBLE
THERMAL
DRYER
SKETCH OF TYPICAL SITE LAYOUT
PREPARATION FACILITIES
THE M.W. KELLOGG COMPANY
HOUSTON, TEXAS
GATES ENGINEERING COMPANY
CONSULTANTS
DENVER BECKLEY CHICAGO
SCALE: i"=20o' 229 DATE: 5/7/74
12
-------
APPENDIX E
PLOT PLANS OF OTHER POWER PLANTS
230
-------
N
-------
APPENDIX F
CONVERSION FROM ENGLISH TO METRIC UNITS
237
-------
APPENDIX F
CONVERSION FROM
To Convert from
acre
atmosphere (normal)
atmosphere (normal)
barrel (42 US gallons)
British thermal unit (Btu)
Btu/hour
Btu/pound mass
Btu/pound mass - F
foot
foot2
foot3
foot /minute
foot-pound force
gallon (US)
gallon (US)/minute
grain
horsepower
inch
inch H20(60°F)
mile (US statute)
pound force
pound mass av
pound mass av
2
pound force/inch
pound mass/foot3
°Rankine
ton mass (US short)
ton mass (US long)
yard
yard3
ENGLISH TO METRIC UNITS
To
2
meter
bar
pascal
meter3
joule
watt
joules/gram
joules/gram - °K
meter
meter
meter
meter3/minute
joule
meter-*
meter3/hour
milligram
kilowatt
centimeter
kilopascal
kilometer
newton
kilogram
metric ton (.tonne)
kilopascal
kilograms/meter
°Kelvin
kilogram
kilogram
meter
meter
Multiply by
4046.9
1.01325
101,325
0.15899
1055.1
0.29307
2.32600
4.18680
0.30480
0.09290
0.02832
0.02832
1.35582
0.00379
0.22712
64.7989
0.74570
2.5400
0.24884
1.60934
4.44822
0.45359
0.0004536
6.89476
16.0185
0.55556
907.185
1016.05
0.91440
0.76455
238
-------
APPENDIX G
LINEAR COMPUTER PROGRAM PRINT-OUTS (ABRIDGED)
239
-------
Linear Computer Program Print-outs (Abridged)
DEFINITION OF TERMS
IN LINEAR COMPUTER PROGRAM PRINT-OUT
COSTTOTL
TPIT
TFRT
TASK
TSC1
TSC2
TWSH
TREF
TSTO
TBRN
AML
DDL
EDL
WMLDL
WS ML SL
X ML PL DL
XS ML PL DL
Y ML CL DL
YS ML CL SL
SS1SL
Total system cost: $/D
Total coal pithead cost: $/D
Total freight cost: $/D
Total ash disposal cost at power plant: $/D
Total capital based scrubbing cost: $/D
Total sulfur related scrubbing cost: $/D
Total coal cleaning cost: $/D
Total refuse disposal cost from coal
cleaning plant: $/D
Total storage/transfer cost (whether at a
transfer point or cleaning plant): $/D
Arbitrary penalty assigned if system cannot
meet specification: $/D
Total coal used from each mine: T/D
Total energy requirement of each power
plant: MMBtu/D
Total S0? emission from each power plant:PPD
Uncleaned coal shipped directly from a mine
to a power plant: T/D
Same as WMLDL but scrubbed at power plant
SL: T/D
Uncleaned coal shipped from a mine to a power
plant via an intermediate point (PL): T/D
Same as X ML PL DL but scrubbed at power
plant SL: T/D
Coal shipped from a mine to a cleaning
plant (CL), cleaned, and then shipped 'to a
power plant: T/D
Same as Y ML CL DL but scrubbed at power
plant SL: T/D
Size of scrubbing system installed at
power plant SL: MMBtu/D
240
-------
SS2SL (MMBtu/D) (%S)
SM SL Variable used in KELPLAN'S model to simulate
the scrubbing system at power plant SL
CC1 CL Size of cleaning plant installed at location
CL: T/D feed
C N CL Same as SM SL but for cleaning system
IN12SL or Scrubbing plant indicator (integer variable).
IN23SL If equal to zero, plant does not exist; if
equal to one, plant exists (at SL).
IM12CL Cleaning plant indicator (integer variable).
If equal to zero, plant does not exist; if
equal to one, plant exists (at CL).
241
-------
Case 1: Spec. = 20 Ib SO2/MMBtu
to
*>
to
-------
PAGE
39 - 74/212
hi IMOCO j_Rfiy .m .
1 rOSTTOTl
? roSTPTT
3 COSTFRT
4 COSTASH
5 CnSTSCl
f> COSTSC2
7 COSTWSH
R CQSTRFF
9 COSTSTO
10 COSTBRN
11 AMA
12 AMB
13 AMC
14 AMC
15 AME
16 AMF
17 AMG
18 AMH
19 DDA
?0 DOB
to 71 ODC
* 2? ODD
w 23 DOE
24 DDF
25 DDG
26 DDH
?7 DDI
28 DDJ
29 DDK
30 DDL
31 DOM
32 DON
33 onn
34 DDP
35 000
36 DDR
37 EDA
38 EDB
39 EDC
40 EDO
41 FOE
42 EDF
43 FDG
44 *=DH
45 EDI
4f> EOJ
47 EOK
48 EDL
49 EDM
AT
BS
E0_
EO
EO
EO
EO
EO
EO
EO
EO
BS
BS
BS
BS
BS
BS
BS
BS
EO
EO
EO
FO
EO
EO
EO
EO
EO
EO
EO
- « ACT I V-W-Y-^»»
318475.25054
'
:
9499.41084
11383.36038
7097199399
.
18684.00000
12994.00000
17726. OOOCO
20023.00000
24504. COOOO
59525.00000
64862.00000
64937.00000
43219.00000
67512.00000
33461.00000.
StACK-ACT-IVITY-
318475.25054-
41349.56689
50000.00000
40500.58916
38616.63962
50000.00000
42902.00601
5000C. 00000
50000.00000
*
*
EO 87017.00000
EO 31570. COOOO
EO 115682.00000
EO
EO
EO
EO
BS
BS
BS
BS
. BS.
BS
BS
BS
BS
BS
. BS .
BS
BS
25608.00000
51307. OOOCO
31488.00000
18259.00000
253180.45174
176077.22061
91953.86293
103676.35876
127123.12316
308806.88485
762474.61583
763356.26604
585645.79019
350242.25804
. 57328.97398
1179137.41006
427794.20154
120499.54826
83802.77939
262560.13707
296583.64124
362956.87684
881693.11514
53476b. 38416
535383.73395
278734.20981
999997.74195
611891.02602
561202. 58994
20J605. 79845
..LOWER LIMIT*- UDDCD i IMIT. HIIAI APTIUITV
NONE
*
NONE
NONE
NCNE
NCNE
NCNE
NONE
NONE
NONE
18684.00000
12994.00000
17726.00000
20023.00000
24504.00000
59525.00000
64862.00000
64937.00000
43219.00000
67512.00000
33461.00000
87017.00000
31570.00000
115682.00000
25608.00000
51307.00000
31488.00000
18259.00000
NONE
NONE
NCNE
NUNE
NCNE
NONE
NONE
NONE
NONE
NCNE
NONE
NUNE
NONE
NONE
50000.00000
50000.00000
50000.00000
50000.00000
50000.00000
50000.00000
50000.00000
50000.00000
18684.00000
12994.00000
17726.00000
20023.00000
24504. 00000
59525.00000
64862.00000
64937.00000
43219.00000
67512.00000
33461.00000
87017.00000
31570.00000
115682.00000
25608.00000
51307.00000
31488.00000
18259.00000
373680.00000
259880.00000
354520.00000
400460.00000
490080.00000
1190499. SS999
1297239. S9999
129B 739. 99999
864380.00000
1350239.99999
669220.00000
1740340.00000
631400.00000
.00000
.00000
.00000
.00000
.00000
.00000
29.29178
I. 00000
I. 00000
*
*
1 3435 8-
.34358-
.38662-
.43.181-
.41473-
.39867-
.47599-
.47599-
.39444-
.39114-
.49105-
.39307-
.46043-
.36617-
.34676-
.3*725-
.38235-
.36581-
m
-------
.MPSX-PT«=16. EXECUTOR. HPSX RELEASE 1 MOO LEVEL 4
-NUMUEJL. ....BOW.... AT . . .ACTI Vl.TY.... . SLACK ACT IVJTY
,LOWFR_LIMIT
.UPP_ER_LJMITj
PAGE
.DUAL ACT1VUY
40 - 74/212
50 EON
...51 EDO
52 EOP
53 EDO
55
56
57
58
59
60
61
62
63
A 64
A 65
A 66
* 67
68
A 69
A 70
71
72
73
74
75
M 76
i£^
A 79
80
fll
82
A3
R4
A 85
86
87
88
R9
90
91
92
91
94
95
96
97
98
99
100
SIZXOF
SIZXOG
SIZXDI
SIZXOJ
SIZXOL
SIZXOM
SIZXDP
SIZXDO
E01PF
E010G
E010T
E01DJ
Eoint
E01HM
E01DP
E0100
E02J1F
F02DG
F02DI
E02DJ
F020L .
E02DN
E02PP
E0?00
E03DF
F03DG
E03CI
E03HJ
F010L
F03DM
E03DP
F0300
F05DF
EO 5CG
E050I
EQ5DJ
E05DL
E05PM
E050P
E05DO
F06CF
"E06PI "
E06DJ
F06DL
F06DM
BS 198198
BS 30103C
BS 266173
BS 163355
BS 214640
OF EO
OG EO
DI EO
OJ EO
OL EO
DM EO
DP EO
DO EO
F BS
G UL
I UL
J UL
L UL
M UL
P UL
0 UL
F BS
G BS
I 8S
J BS
L BS
H UL
P BS
0 BS
F UL
G BS
I BS
J BS
L BS
M UL
P UL
0 BS
F as
r, BS
I BS
J BS
L BS
M as
P BS
9 BS
F EO
r. EO
I EO
J EO
L EO
1 EO
80960 2115441
64910 .211129
11787 759966
08089 466404
68346. 150539
1
1
1
1
1
1
1
1
19039
35089 _ .
88213
91910
41654
NCNE 2313639
NONE 512160
NONE 1026140
NONE 629759
NONE 365180
NONE
NGNE
NONE
NCNE
NONE
NONE
NONE
NONE
NONE
NONE
NCNE
NCNE
NCNE
- -
00000
00000 .
00000
00000
00000
00000
00000
00000
NONE
NONE
NONE
NCNE
NONE
NCNE
NCNE
NONE
NONE
NONE
NCNE
NONE 1
NONE
NCNF
MONE
NONE
NCNE
NONE
NCNE
99999
00000
00000
99999
00000
14473
2412
14473
00000
00000
00000
00000
00000
00000
00000
00000
16885
18274-
09 965
18328
09965
20293-
-------
.MPSX-PTF16. EXECUTOR.
-JJ1JMRE.R-. ....ROW.^. A.T- .
PPSX RELEASE 1 MOD LEVEL
.ACTIVITY^.., SLACK. ACTIVITY.
LOWF P.__JMIT . __ ..UPPER LIMIT.
PAGE
.DUAL ACTIVITY
41 - 74/212
A
...A
A
A
A
A
A
A
A
A
A
A
A
M
_ III
. -_.
101 E06DP
.. _ 102 E060Q.
103 HDF
104 HOG
105 HOL
106 HDJ
107 HDL
108 HDM
109 HOP
110 HDO
111 JDF
112 JOG
113 JDI
114 JOJ
115 JDL
116 .10 M
117 JDP
118 JOO
119 SIZYON
V20 SIZYDP
121 SIZYMA
172 SIZYMB
J23 SI7YMC
124 SIZYMD
125 SIZYPA
'_. .126. STZYPB
127 E003DN
128 FOtnnP
129 F003MA
130 F.003MB
131 F001MC
_ 132 EOC3MO
133 F003PA
134 F003PB
135 FDN
136 FOP
137 FMA
- J38. FMB
139 FMC
140 PMP
_ _14L_ FpA
142 FPB
EO
_ EO
EO
EO
EO
EO
EO
FO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
FO
EO
EO
F.G.
EO
FO
FO
FO
EO
_ EO
EO
EO
EO
EO
EO
EO
EO
EO
FO
EO
-
1
"
.09765-
I 182 74-
.03150
j
.03150
.03150
.38412-
1.90000
1.900UO
1.90000
1.90000
1.90000
1.90000
.22675
.38412-
1.90000
1.90000
1.90000
1.90000
1.90000
1.90000
.2267!i
-------
.MFSX-PTF1A. FXFCUTOR.
SECTION 2.-.COLUMNS
- MJMBFR - .COLUMN.- AT- .
HPSX RELEASE 1 MOD LEVEL 4
PAGE
42 - 74/212
.ACTIVITY... -..-INP-UT COST,
..LCUER-IIMIT.
.UPPER LIM1JN
.PEPUCED COST.
145
. I"
191
199
709
733
741
25?
255
7A6
._ 279
295
305
371.
338
1146
us*
1567
7394
7588
3858"
4766
4890
W b106
£ 5730
O\ bib?.
6517
66H9
6800
6801
6802
6803
6P04
6805
6806
6807
6812
6P13
6815"
0816
6819
682?
6875
6878
6830
6831
6813
6834
6835
WMCDA
WMCCB
MM ADO
WMARH
WMCOI
WMCCl
WMCOM
WMFON
WHADn
wMnnp
WMAOR
WSWADG
WSMCOI
HSMCOl
XMDOPDC
XMDOPDD
XMCOPDE
XMDOPDF
XMCDPOJ
XMFONOK
XMDnPOO"
XSMOHPOF
XS.MDDPDJ
XSMCOPOM""
XSMOOPDO
YMDDNnK
VSMDPBCF
VSMAMADM
ssior,
ssini
SS10.)
ssini
SS1DM
ssinp
SSI 00
ss^np
SS2HM
SS2DP
S1HF
S2CF
S20G
s?ni
S2PJ
S70L
S1DM
S20M
SI OP
S20P
S30P
BS
BS
BS
BS
as
BS
BS
RS
BS
BS
BS
BS
BS
.BS
BS
BS
BS
as
as
AS
BS"
BS
us
BS
as
BS
as
BS
as
i)S
as
as
as
as
BS
BS
as
us
RS
AS
BS
as
as
as
BS
as
BS
BS
BS
917.32129
637.96151
3230.82464
3234.56045
2121.90691
4272.24077
Ii49. 98036
5b05. 52249
1275.55360
2146.55740
909.49442
741.61180
837.71257
1025.18648
2490.37610
2824.53434
1592.47150
1317.37968
,
»
__
-
~~
.
~ ~~
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NCNE
NCNE
NCNE
NONE
NONE
NONE
NONE
NONE
NCNE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NCNE
NCNE
NC.NE
NCNE
NONE
NONE
NONE
NONE
NONE
NCNE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
-------
.MPSX-PTF16. FXECUTDP. MPSX RFLEASE I MOO LEVEl 4
. NUMBER. ..COLUMN^. AT ....ACTIVITY^.. .^JNP.UT CCST.. . .LOKE R. JJ.MIT,
PAGE
43 - 7W212
.... UP. PJEJLJLJJ* IT. .RPPUCEP COST.
6836
_ _ 6837
6d)9
6840
6R4L
6842
6R43
. ... 6844
6R45
6846
6849
6851
6853
6F55.
6857
6859
686Q_
6881
6882
6881_
6885
6flfi6
_ _ 6R88
6889
6890
_H_689l_
6P92
6H93
6R94
6895
6898
6R99
6900
6901
_ f902
6903
6904
_.6905..
6906
6907
._ 690R.
6909
6910
6911.
6913
to
SlOO
S2DO __
CC1DN
cr.iop
CC1MA__
fClMB
CCIMC
cciMn ._
CC1PA
CC 1PB
cinp
C1MA
C1MB
C1MC
C1MO
CIP*
C2PA
TPIT
TFRT
TASH ....
TSC2
TWSH
rSTJ _.
TRPN
IN12DF
IN 120 I
IN120J
IN12DL
IM12DM
IN230F
IN230G
IN23H1
IN23DJ
IN23DL.
IN230M
IN23DP
TN2300_
IM12DN
TM120P
IM12MA
IM12M8
IM12MC
IM12MO
iMiapR
BS
BS
BS
as
BS
BS
BS
BS . . .
BS
BS
us
BS
BS
BS
as
BS
BS
as 219516.61397 1
RS 90935.21831 1
B.S . _. 4774.6^592_ 1
OS . 1
BS . 1
BS 3248.78234 1
BS . 1
IV
IV
IV
IV
IV
IV
IV
IV
IV
IV
IV
IV
IV
IV - .
IV
IV
IV
IV
IV
IV
IV
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NCNE
NONE
NONE
NONE
NCNE
NCNE
NONE
NONE
NCNE
NONE
00000 . NONE
00000 . NONE
00000 . NONE
00000 . NONE
00000 . NONE
00000 . NONE
00000 . NCNE
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
,1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
. 1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
-------
to Case 1: Spec. = 5 Ib SOn/MMBtu
ib £.
CO
-------
MPSX RELEASE 1 MOO LEVEL 3
PACE
18 - 74/165
NUMBER .. .ROW. .
1 COSTTOTL
2 COSTPIT
3 COSTFRT
4 COSTASH
5 COSTSC1
6 COSTSC2
7 CnSTWSH
8 COSTRFF
9 COSTSTO
10 COSTBRN
11 AM A
12 AMB
1 3 A.MC
14 AMP
15 AMP.
16 AMF
17 AMG
18 AMH
19 OD A
20 DD 8
10 21 DOC
* 22 ODD
*° 23 DD F
24 DDF
25 DOG
26 DOH
27 DDI
28 DDJ
29 DDK
30 DDL
31 OHM
32 DON
33 non
34 OOP
35 nno
36 DD»
37 EDA
38 FDA
39 EOC
40 EOD
41 FnF
42 EOF
43 EOG
44 EDH
45 EDI
46 FDJ
47 FDK
48 EDL
49 EDM
_AI
BS
EO
EO
EO
EO
EO
EO
EO
EO
EO
BS
BS
BS
BS
BS
BS
BS
BS
EO
EO
EO
EO
FO
EO
EO
EO
EO
EO
FO
j^.AC_TJ_₯UY_._._._
'358183.05216
508.37364
2406.44351
534.43454
19741.47872
7683.51512
3fll3. 71776
18684.00000
12994.00000
17726.00000
20023.00000
2.4504. 00000
59525.00000
64862.00000
64937.00000
43219. 00000
67512.00000
33461. OOOCO
^LACK ACTIVITY
358183.05216-
*
49491.62636
47593.55649
49465.56546
30258.52128
50000.00000
316.48488
4186.28224
*
EO 87017.00000
EO 31570.00000
EO 11 56B2.0OOOO
EO
EO
FO
EO
UL
UL
UL
UL
III
UL
UL
UL
UL
UL
BS
UL
UL
25608.00000
51307.00000
31688.00000
18259.00000
93420. COOOO
64570. 00000
88630.00000
100115.00000
1225? 0, 00000
297625.00000
324310.00000
324685. 00000
216095. 00000
337560.00000
57328.97398
435085.00000
157850.00000
1 0997A. 02&02
..LOWrR LIMIT.
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
18684.00000
.12994. 00000
17726.00000
20023.00000
24504.00000
59525.00000
64862.00000
64937.00000
43219.00000
67512.00000
33461.00000
87017.00000
31570.00000
115682.00000
25608.00000
51307.00000
31488.00000
18259.00000
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
..UPPER LIMIT. .DUAL ACTIVITY
NONE
50000.00000
50000.00000
50000.00000
50000.00000
50000.00000
8000.00000
8000.00000
18684.00000
12994.00000
17726.00000
20023.00000
24504.00000
59525.00000
64862.00000
64937.00000
43219.00000
67512.00000
33461.00000
B7017. 00000
31570.00000
115&B2. 00000
25608.00000
51307.00000
31488.00000
18259.00000
93420.00000
64970.00000
88630.00000
100115.00000
122520.00000
297625.00000
324310.00000
324685.00000
216095*00000
337560.00000
167305.00000
435085.00000
157850.00000
1*00000
1.00000
1.00000
1.00000
.25232
1.00000
.74690
1.00000
1.00000
.00007
I&6753-
.66753-
.49089-
.54416-
.52^13-
.50541-
.59738-
.59738-
.66978-
.49633-
.4910S-
.60096-
.66119-
.36*17-
.58785-
.45549-
.4857A-
.62192-
.02391
.02010
.02127
.0210
-------
MPSX-PTF13 EXeCUTOR. MPSX RELEASE 1 MOD LEVEL 3
NUMBER ...ROW.. AT ...ACTIVITY... SLACK ACTIVITY
..._L OWE R _LJ MIT. . ._UPP_ER_ UM t T._
PAGE
DUAL-ACT IV 1T Y
19 - 74/165
50 EON
51 EDO
52 EDP
53 EDO
54 FDR
55 SIZXOF
56 SIZXDG
57 SI7XDI
58 SIZXDJ
59 SIZXOL
60 SIZXOM
61 SIZXOP
62 SIZXOO
63 F010F
64 FO 1 OG
65 E01DI
A 66 FQ1DJ
A 67 F01DL
A 68 EOIDM
69 F010P
A 70 F01DO
71 E020P
72 F020G
N> 73 E020I
£ 74 E02DJ
75 P02DL
76 F02DM
77 E020P
78 F0200
79 E03DF
A 80 EQ3DG
81 E03DI
B2 E03DJ
83 F030L
84 F03DM
B5 E03DP
86 RO^OO
87 E050F
88 E050G
89 E050I
90 E050J
91 E050L
97 F050M
93 F_05nP
94 E0500
95 EQ6DF
A 96 FOftDG
A 97 E06fll
98 F060J
A 99 E06DL
100 E060M
BS' 1*8198.80960
UL 128040.00000
UL 256535.00000
UL 157440.00000
UL 91295.00000
EO
EO
FO
EO
EO
FO
EO
EO
BS
BS
BS
UL
UL
UL
AS
UL
BS
RS
BS
UL
BS
UL
BS
UL
UL
UL
BS
BS
BS
BS
BS
BS
BS
as
BS
as
BS
BS
as
BS
EO
EO
EO
F.O
EO
EO
380211.19039
r
1.00000
1.00000
\.00000
1.00000
1.00000
1.00000
1.00000
1.00000
-
.
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NCNE
NONE
NONE
NONE
NONE
NONE
.
576410*00000
U8040. 00000
256535.00000
157440.00000
91295.00000
-
ilooooo
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
.
.02221
.01894
. 01 993
.02195
.06490
.06490
.06490
.06110
.06490
.06110
.06490
.06110
*
60U71767
601.71767
601.71767
551.57453
55 il 57453-
601.71767-
601.71767-
-------
MPSX-PTF13
EXECUTOR. MPSX RELEASE I MOD LEVEL 3
PAGE
20 - 74/165
_NliK B_E P - ._._RO W ._,
J ._._._A_CUvm...... SLACK_AC.! Jy_iTY ...j.OMEAJ. I.MJJ.._...UPP EJL_U HIT. .DUAL ACTIVITY
A 101 E060P
102 E06DO
103 HOP
104 HOG
105 HOI
106 HOJ
107 HDL
10H HOM
109 HOP
110 HOO
111 JOF
112 JOG
113 JO!
114 JD.I
115 JOL
116 JDM
117 JDP
118 JDO
119 STZYON
120 ST7vnp
N> 121 SIZYHA
Ui 122 SIZYMB
I-1 12^ ST7YMC
124 SIZYMD
125 SIZYPA
126 ST7YPB
127 E003DN
128 F003DP
129 F003MA
130 FQ03MB
131 F003MC
112 FOOVin
A 133 HJ03PA
A 134 E003P8
135 FON
136 FOP
137 FMA
na FMB
139 FMC
140 FMD
141 FPA
14? FPB
EO
EO
EO
EO
PQ
EO
EO
to
EO
EO
FO
FO
FO
FO
EO
EO
EO
EO
EO
FO
EO
EO
FO
EO
EO
FO
EO
EO
EO
EO
EO
FO
EO
EO
FO
EO
EO
FO
EO
EO
EO
EO
A01. 71767-
.06490
.06490
.0&49O
.06110
.06490
. Ok 1 1 O
.06490
.06110
... .O1OO&
.03150
. .02665
.0103?
.03150
. .01586
.00759
.01031
1.41912
1.41912
.41912
-41912
.41912
.41912
... 1-41012
.35558-
.41912
- . - - 41Q)7
.41912
.41912
- .41912
.41912
-------
MPSX-PTF13 EXECUTOR
_SFCJ_ION 2 - COLUMNS
MPSX RELEASE i HOD LEVEL 3
PACE
21 - 7A/165
NUMBER
145
153
232
252
255
266
268
303
370
329
. . 338.
509
717
9? a
5*0
1146
1149
1354
1357
1562
tsj 1564
Ul 1770
10 1773
1978
1981
21 86
2189
2394
7396
2588
2813
30 18
3021
3437
3858
3860
4066
4766
4890
5730
6087
6215
6799
6300
6801
6802
6803
6804
.COLUMN.
WMCDA
HMCDB
WMBDL
WMF ON
WMADO
WMDOP
MM FDP
_.WSMAOI
WSMBOL
WSMCDM
USlDOP
XMGONDA
XMGHNOB
X.XODPOC
_. XMGOP.OD
XMnnPDE
XMGOPOE
X1DOPOF
XMFDPDF
xvinoPOG
XMGDPDG
XMOPPDH
XMGDPOH
XSOOPOI
XMGOPDI
XMOOPDJ
XMFDPOJ
XMFDNOX
XMGDPDL
XMOOPOM
XMGOPDM
XMGDPDO
XVIOOPDO
XX FOP DO
XMGOPDR
AT
BS
BS
BS
BS
BS
BS
BS
BS .
BS
BS
. BS _.
BS
BS
BS
BS
BS
BS _
BS
BS
BS
BS
BS
_.BS _.
BS
BS
BS
BS
BS
BS
BS
BS
. B S
BS
BS
__BJL_
BS
BS
as
...ACTIVITY
315.21482
219.21972
2406.44351
5505.52249
508.37364
2030.50337
132.01616
535.06565
372.11748
701.51642
45.61012
803.97414
35.18394
983.89763
43.05784
2355.73534
153.16159
2604.37349
113.97396
2607.38493
114.10575
1735.35225
75.94340
2671.82536
173.71265
1592.47150
1764.72641
1267.61541
55.47405
671.98501
1246.15530
81.02062
733.14507
32.08428
XSMDDPDF BS
XSMCDPOJ BS
XSMODPOO BS
YMDDPDI
YKBMBDL
SSIDF
ss me
ss ini
SS 10J
SS1DL
SSIDM
BS
BS
BS
BS
BS
B_S
BS
BS
"
INPUT COST.. ..LOWER LIMIT. ..UPPER LIMIT. .REDUCED COST.
NONE
NONE
NONE
. NONE
NONE
NONE
NONE
NONE
NONE
NONE .
NONE
NONE
NONE
NONE
NONE
NONE .
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE .
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NOME
-------
c.
PAGE
22 - 74/165
6805 SS10P
A BOA SSI DO
6808 SS20G
6811 SS20L
6815 S10F
6817 S30F
6820 S30G
6824 S1DJ
6826 S30J
6879 S301
6830 SI DM
6832 S30M
684S S*OP
6836 SI 00
6838 S300
6840 CC10P
6841 CC1MA
6842 CC1MB
6843 CCIMC
6844 CC1HD
#,««.«> rr.iPA
ro 6846 re IPS
W 6847 flDN
<*» 6851 riMA
6853 C1MB
6855 C1HC
6857 riMD
6858 C2MD
6859 C1PA
6861 riPR
6874 OOL
6881 TPIT
688? TFRT
6883 TftSH
6885 TSC2
A«87 TRFF
6888 TSTO
6891 IN12DG
6892 TN120I
6A93 INI120J
6R94 IN120L
6895 IN170M
6896 IN12DP
6897 IN1200
689ft TN23DF
6899 IN230G
6901 TN230J
BS
BS
BS
BS
RS
BS
BS
BS
BS
BS
BS
BS
as
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS 141748.93762
BS 4197.83093
BS
as
BS 7071.20087
IV
IV
IV
IV
TV
IV
IV
IV
IV
IV
UHF w i \.uo i . . . .bwni^n. kinii. ..uri-cn i, I n i I . ^ .n [, yui. cu 1. uo I .
NONE
r NONF
NONE
NONE .
NONF
, NONE .
NONE
NGNF
NONE
i NONE
NONF
NONE
NONE
MONF
NONE
NONE
NONF
NONE
NONE
NONF
NONE
NONE
NDNF
NONE
NONE
NflNF
NONE
NONE .
NONF.
NONE
NONE
MQNF
NONE
1.00000 . NONE
1.00000 . NHNF
1.00000 . NONE
1.00000 . NONE .
1.00000 . NONF
1.00000 . NONE .
1.00000
1.00000
1.00000 .
1.00000
1-nnnnn
1.00000 .
1.00000
l.OOOOO
1.00000
1.00000
- i-ooooo
6903 IN23DN
IV
1.00000
-------
EXECUTOR. MPSX RELEASE 1 MOO LEVEL 3
NUMBER .COLUMN. AT ... ACTIVITY INPUT .._CQST.j__. ._L PWE_R_kl M '!__
6905 TN23DO
6906 IM12DN
6
-------
Case 1: Spec. = 3.1 Ib SO_/MMBtu
01 2.
-------
MPSX-PTF13 EXECUTOR. MPSX RELEASE 1 MOD LEVEL 3
SFC.TION 1 - RflwS
PAGE
15 - 74/168
NUMBEP
1
?
3
4
5
6
7
8
a
10
11
12
13
14
15
16
17
IP
19
?0
NJ 21
S "
23
24
25
?ft
71
?8
?<3
30
31
3?
33
44
35
36
37
3fl
39
40
41
4?
43
44
45
46
47
4fl
49
.. .ROW..
COSTTOTl
cnsipn
COSTFRT
COSTASH
COST SCI
cnsTscz
COSTWSH
COSTREF
COSTSTO
COSTBRN
A1A
AM3
A,«r
AIT
AV.E
ANC
Air.
A«H
nnA
OD«
DDC
ODD
DDE
DDF
DOC
r>DH
PDI
noj
OIK
00 L
DDM
nnN
nun
nos>
noo
DDR
FOA
EDS
Enc
FOO
FDE
EOF
For,
EHH
FOI
POJ
ERK
COL
FOM
AT
BS
EO
EO
EO
FO
EO
EO
FO
EO
EO
BS
BS
RS
BS
BS
BS
BS
BS
FO
EO
EC
FO
EO
EO
FO
FO
EO
FO
EO
EO
EO
FO
EO
FO
FO
EO
UL
UL
UL
UL
UL
UL
UL
Ul
UL
UL
BS
UL
UL
...ACTIVITY...
384574.83811
292^59705
13D5. 04147
307. 59668
9^78.63212
13605I68468
9818. 65797
18684. OOOCO
12994. OOOCC
17726.00000
20023.00000
24504. OOOCO
59525.00000
64862. OOOCO
64937. COOCO
43219. OOOCO
67512.00000
33461.00000
R7G17. OOOCO
31570. OOOCO
115682. OOOCO
25608.00000
51307.00000
314r8. 00000
18259. OCOOO
57920.38672
40281.39063
54950. 58984
62071.28516
T5S62. 37500
164527.43750
201072. 12500
201304.62500
133978. 875CO
209287. 125CO
57323.97398
2t9752. 62500
97E66. 93750
SLACK ACTIVITY
384574.83811-
49707^40295
48614.95853
49692.40332
40021.36788
50000.00000
36394.31532
40181.34203
fOOOO. 00000
«
46400.08852
..LCWER LIMIT.
NONE
*
NONE
NCNE
NONE
NONE
NONE
NCNE
NCNE
NONE
18684.00000
12994.00000
17726.00000
20023.00000
24504.00000
59525.00000
64862.00000
64937.00000
43219.00000
67512.00000
33461.00000
87017.00000
31570.00000
115682.00000
25608.00000
51307.00000
31488.00000
18259.00000
NONE
NONE
NONE
NCNE
NCN =
NCNE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
..UPPER LIMIT.
NONE
soooolooooo
50000.00000
50000.00000
50000.00000
50000.00000
50000.00000
50000.00000
50000.00000
18684.00000
12994.00000
17726.00000
20023.00000
24504.00000
59525.00000
64862.00000
64937.00000
43219.00000
67512.00000
33461. OOCOO
87017.00000
31570. OCCOO
115682.00000
25608. OOCOO
51307.00000
31488.00000
18259.00000
57920.38672
40281.39063
54950.58984
62071.28516
75962.37500
184527.43750
201072.12500
201304.62500
133978.87500
2092R7. 12500
103729.06250
269752.62500
97866.93750
.DUAL ACTIVITY
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
8.37942-
1.00000
.00007
166753-
.66753-
.49089-
.54416-
.52313-
.50541-
.59738-
.59738-
.66970-
.49033-
.49105-
.68096-
.66119-
.36617-
.58785-
.45549-
.48574-
.62192-
.02391
.02391
.02010
.02127
.02109
.02058
.02174
.02174
.02237
.02028
.02505
.02230
-------
MPSX-PTF13 EXFCUTOR. MPSX RELEASE 1 MOO LEVEL 3
MJMPER ...ROW.. AT ...ACTIVITY... SLACK ACTIVITY* ..LCWER LIMIT. ..UPPER LIMIT.
50
51
52
54
55
56
57
58
60
61
6?
63
64
65
66
67
68
70
71
77
SO 73
Ul 74
'J 75
76
77
78
79
80
fll
f>2
83
S4
86
87
an
39
90
91
92
93
94
95
9ft
97
98
99
100
EON
EOP
enp
mo
FOP
S1ZXDF
SIZXDG
sizxni
SIZXDJ
STZXOL
SI7XIJM
S» ZXOP
sizxno
FOIDF
F.oinr,
F01PI
Foinj
roiCL
CCIP.M
EOino
FQ2P.F
F02RG
E02DI
F02DJ
E02DM
EO^OF
Eoinr,
F03ni
F03D.I
E330L
=03PM
E01DP
P050F
FO-5P.1
£0501
F050M
E05DP
E05DO
F06DF
F06HG
£0601
E06PJ
E06RL
E060".
BS 1 S81S8. 3,1960 160415. 31*>40
UL 793P4. 75000
UL 159051. 625CO
UL 97612. 750CO
UL 56607.88672
EO
EO
FO
FO
EO
FO
EC
EO
RS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS .
UL
BS
BS
RS
BS
Ul
UL
UL
BS
Ul
UL
UL
UL
BS . 1.00000
BS . 1.00000
RS . 1.00000
HS . 1.00000
<5S . 1.00000
BS . 1.00000
BS . 1.00000
BS . 1.00000
EO
EO
EO
EO
EO
FO
NONE 358614-.12500
NONE 79384.75000
NCNE 159051
NCNE 97612
NCNE 56602
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NGNE
NCNE
MCNE
NONE
NONE
NCNE
NCNE
NCNE
NCNE
NCNE
NONE
NCNF
NCNE
NONE
NONE
NONE
NONE 1
NONE 1
NONE 1
NCNE 1
NONE 1
NONE 1
NONE 1
NONE 1
62500
75000
88672
PAGE 16 - 74/168
.DUAL ACTIVITY
.02221
.01894
.01993
.02195
.25720
.25720
.25720
.24214
.25720
.25720
.25720
.25720
2384!72727
v
2186.00000
2186.00000
2186.00000
2186.00000
2186.000JO
00000
2186.00000
2186.00000
00000
00000
00000
00000
00000 .
00000
00000
2186.00000-
2186.00000-
2166.00000-
2384.72727-
2186.00000-
2186.00000-
-------
MPSX-PTFH
EXECUTOR. KPSX RELEASE 1 MOO LEVEL 3
.ACTIVITY... SLACK ACTIVITY ..LOWFR LIMIT.
PAGE
17 - 74/168
. . U PPER LI MIJT. . DUAk_*.CLI.V 1.7 X_
101
10?
103
104
105
F.06DO
HOP
HTG
106 HDJ
107 HDL
108 HIM
109
10
11
12
13
14
15
116
117
lift
119
120
121
172
121
K> 124
£ 125
00 126
a 127
A 128
A 129.
A 1 30
A 131
A 13?
133
A 134
M5
11 1
138
M9
140
141
14?
HDP
HDO
JOF
.me
.101
JOJ
jnp
jno
S! 7YON
S! 7.YOP
SI7YMA
SI 7YMB
S17YMC
SI7.YMD
SI 7YPA
STZYPIJ
FUO'DN
F002DP
F.OC3M1
EOOHMC
F001MC
FOO"?PA
F003P8
FDN
r-A
pljp
FPB
EO
EO
EO
EO
EO
FO
Ed
p.d
EO
EO
FO
FO
EO
EO
FO
FO
FO
EO
EO
EO
EO
EO
= 0
EO
FO
EO
FO
EO
EC
= 0
EO
EO
EO
EC
ro
EO
FO
F.O
EO
EO
EO
2186.00000-
2186.00000-
.25720
.25720
.25720
.24214
.25720
.25720
.00085
.00238
.03150
.02568-
.00176-
.OJ150
.03130
.03150
.03150
.03150
1.90000
1.90000
1.90000
1.90000
1.90000
1.90000
1.90138-
1.90000
.
'.'.'.'.
27369.92598-
1.90000
1.90000
1.90000
1.90UOO
1.90000
1.90000
1.90138-
1.90000
-------
MPSX-PTF13 EXECUTUR. MPSX PELFASE 1 MOO LEVEL 3
SFCTION 2 - COLUMNS
PAGE
IB - 74/168
NUMBER
1*5
153
?32
252
755
?66'.
260
297
340
509
717
938
94C
1146
1 14S
1 354
1357
156?
I 5iS4
|sj 1770
Ul 1 773
*° 1<578
1981
2186
2189
?3
-------
MPSX-PTF13 PXf-CUTnR. MPSX RELEASE 1 MOD LEVEL 3 PAGE 19 - 74/168
NUMBER .COLUMN. AT ...ACTIVITY INPUT COST.. ..LOWER LIMIT. ..UPPER LIMIT. .REDUCED COST.
6604 SS2DM.
6605 SS?DP
6606 ss?no
6607 SIOC
6609 S3DF
6610 sine
6612 S30G
6613 SIDT
6615 S30I
6616 SIDJ
6618 S30J
6619 S1DL
6*-21 S3fH
6622 S1DK
6624 S3DM
6625 Sinn
66?7 S3DP
66?8 S1RO
6630 S3DQ
6631 CC10N
6632 CCIPP
6633 CC1CA
6634 CT1MR
N) 6635 CC1VC
<* 6636 CCI!»D
0 66*7 CCIPA
6c3« CCIPB
6639 C1DN
66il CIDP
6643 C1"A
06 -'.7 C1'"C
6ft 'i 9 Cl^'D
f.653 ClDa
6666 OOL
6673 TOIT
6674 T«-1T
6675 TASh
6676 TSft
6677 TSC2
6C-78 TWSH
6"-flO TSTP
6690 'N?3DF
6691 IN23PG
6692 IN230I
66°J IM23n.l
6694 IN?JOL
6695 PJPBDI^
6696 IN?30t>
6697 IM23DC
BS
BS .
BS
BS
BS
BS
BS
BS
BS
RS
BS
BS
BS
RS
BS
BS
BS
RS
BS
BS . .
BS
BS
BS
BS
BS
BS
BS
BS
RS
RS
BS
BS
RS
BS
BS
BS
RS 185501.72070 1.00000
BS 188C99. 55741 1.00000
RS 3301.51418 1.00000
BS . 1.00000
RS . 1.00000
RS . 1.00000
BS 7672.04582 1.00000
IV
IV
IV
IV
IV
IV
IV
IV
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NL'NE
NONE
NONE
NONE
NONE
NUNE
NONE
NONE
NONE
NONE
NONE
1.00000
l.OOCOO
1.00000
1.00000
l.OOCOO
l.OOCOO
1.00000
1.00000
-------
PACE
20 - 74/168
Nlir.Hi- x
6fc99
6700
f>70?
6703
o705
.I.ULUnra.
TM17DN
IM12HP
IK12MA
TM12MB
I»U2«C
I'', 12^.0
01 ... ni. I n
IV
IV
IV
IV
IV
IV
IV
l-Lil.. ..LUWCK L1H1I. ..Uf
«
.
KtK Linil. .KCUU^Cl
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
} V,US 1 .
-------
en
to
Case 1: Spec. = 1.2 Ib SO~/MMBtu
c 2
-------
MPSX-PTF13 EXECUTOR. MPSX RELEASE 1 MOD LEVEL 3
SECTION 1 - ROWS
PAGE
38 - 74/165
NUMBER
1
7.
3
4
5
6
7
R
p
10
11
12
13
14
15
16
17
18
l
26
27
28
29
10
31
3?
33
34
35
36
37
38
39
40
41
42
4?
44
4-5
46
47
48
49
...ROW..
COSTTOTL
COSTPIT
COSTFRT
COSTASH
COSTSC1
COSTSC2
COSTWSH
COSTREF
COSTS TO
COSTBRN
AM A
A»n
AMC
AMD
AVF.
4MF
AMG
AVH
DOA
DOB
DOC
DOD
ROE
OOP
onr,
DDH
DO I
DTJ
DDK
DHL
DOM
OON
DOG
OOP
ODD
DDR
EDA1
EOB
FDC
EOD
cne
EOF
EOG
FOH
EOI
POJ
EDK
EOL
FDM
AT
BS
FO
EO
FO
F.Q
EO
EO
FO
CP m rr
t/i O O
OS
BS
BS
BS
BS
BS
BS
EO
EO
EO
FO
F.O
EO
FO
FO
EO
EO
EO
EO
EO
FO
EO
EO
EO
EO
UL
UL
UL
UL
UL
UL
UL
Ul
UL
UL
UL
UL
UL
...ACTIVITY... SLACK ACTIVITY
413844.04347 413844
.
.
.
.
76.82086 49923
363.64020 44636
80.75896 49919
1622.28924 48377
50000
10193. 04145 39806
22914.55599 27085
50000
18684.00000
12994.00000
17726.00000
20023.00000
24504.00000
59525.00000
64862. OOOGO
64937.00000
43219.00000
67512.00000
33461.00000
87017.00000
31570.00000
115682. OOOCC
25608.00000
51307.00000
31488.00000
1B259. 00000
22420.79297
15592.79688
21271.19531
24027.59375
29404.79297
71429.93750
77834.37500
77924.37500
51862.78906
81014.37500
40153. 19141
104420.37500
37883.99219
04347-
..LOWER LIMIT.
NONE
..UPPER LIMIT.
NONE
.DUAL ACTIVITY
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
«. 37942-
17912
35980
24104
71076
00000
95855
44401
00000
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
18684.00000
12994.00000
17726.00000
20023.00000
24504.00000
59525.00000
64862.00000
64937.00000
43219.00000
67512.00000
33461.00000
87017.00000
31570. 00000
115632.00000
25608.00000
51307.00000
31488.00000
18259.00000
NONE
NONE
NONE
NCNE
NONE
NONE
NONE
NONE
NONE
NGN?
NCNE
NONE
NONE
50000.00000
50000.00000
50000.00000
50000.00000
50000.00000
50000.00000
50000.00000
50000.00000
18684.00000
12994.00000
17726.00000
20023.00000
24504.00000
59525.00000
64862.00000
64937.00000
43219.00000
67512.00000
33461.00000
87017.00000
31570.00000
115682.00000
25f>08. 00000
51307.00000
31488.00000
18259.00000
22420.79297
15592.79688
21271.19531
24027.59375
29404.79297
71429.93750
77834.37500
77924.37500
51862.78906
81014.37500
40153.19141
104420.37500
37883.99219
1.00000
.00007
.66753-
.66753-
.49585-
.54416-
.52313-
.50792-
.59738-
.59738-
.66978-
.50038-
.53542-
.68096-
.66119-
.42550-
.58705-
.46645-
.49158-
.62192-
.02391
.02391
.02300
.02127
.02109
.02204
.02174
.02174
.02237
.02264
.02589
.02505
.02230
-------
HPSX-PTF13
FXECUTDR. MPSX RELEASE 1 MOO LEVEL 3
PAGE
39 - 74/165
NUMBER ...RflW.
AT
.ACTIVITY... SLACK ACTIVITY ..LOWER LIMIT
.UPPER LIMIT. .DUAL ACTIVITY
50
51
52
53
54
55
56
57
58
59
60
61
62
63
64
65
66
67
68
69
70
71
72
to 73
en 74
76
77
7R
79
30
31
92
83
R4
B-5
8A
87
R8
89
00
91
92
93
94
95
96
97
98
90
100
EON
EDO
EOP
EDO
FDP
SIZXDF
SIZXDG
SIZXOI
STZXDJ
SIZXDL
MZXDM
sr ZXDP
S! ZXDO
EOinF
F010G
EOIDT
E01HJ
EQ10L
E010M
poino
E070F
EO?DG
F.02PJJ
E020P
EO'DO
E030G
E0301
F030L
E0300
E050F
PQ5DI
E05DJ
F05DL
F05HM
F050P
F05HO
E060F
F06DG
E060I
F06DJ
E060L
F060M
UL 138818.37500
UL 30729.59375
UL 61568.38672
UL 37785.59375
UL 21910.79297
EO
EO
FO
EO
FO
EO
EO
EO
BS
BS
SS
BS
BS
BS
BS
BS
RS
BS
BS
Ml.
. RS
BS
BS
BS
UL
UL
UL
BS
UL
UL
UL
UL
BS 1
BS . 1
BS . 1
BS . 1
BS . 1
BS . 1
BS . 1
BS . 1
EO
FO
EO
EO
EO
EO
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NCNE
NONE
NCNE
NONE
NONE
NONE
NONE
NONE
NCNE
NONE
NONE
NONE
NCNE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
00000 NCNE
00000 NONE
00000 NONE
00000 NONE
00000 NONE
00000 NONE
00000 NONE
00000 NONE
.
138818.37500
30729.59375
61568.38672
37785.59375
21910.79297
"
-
ilooooo
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
.03463
.02221
.02533
.02334
.02195
.25720
.25720
.25720
.24214
.25720
.25720
.25720
.25720
"
2384.72727
2186.00000
2186.00000
2186.00000
2186^00000
2186.00000
2186.00000
2186.00000
2186.00000-
2186.00000-
2186.00000-
2384.72727-
2186.00000-
2186.00000-
-------
MPSX-PTF13 EXECUTOR. HPSX RELEASE 1 MOO LEVEL 3
NUMBER ...BOW.. _AJ ._..'Ac.!lviIY-'-«_' ?k*?J^ *?TIVITY ..LOWER LIHIT:
PAGE
40 - 74/165
..UPPER LIMIT. .DUAL ACTIVITY
101 E060P
107 E0600
103 HDF
10* HOG
105 HIM
106 HDJ
107 Hf»L
10B MOM
109 HDP
110 MOO
111 .lf)F
HZ JOG
113 JO I
11* JOJ
115 JOL
116 JOM
117 JDP
118 JOO
119 STZYDN
120 SIZYDP
121 SI7YMA
12? SI7YMB
123 SI7YMC
to 124 STZYKO
<* 125 SI7YPA
126 SIZYPB
A 127 E003DN
A 128 PQ03DP
A 129 FQ01MA
A 130 COOV.B
A 131 EOO'^MC
A 132 E003MD
133 E003PA
A 134 E003PB
135 FON
136 FHP
.137 FMA
138 FMB
139 FMC
140 FMD
141 FPA
142 *PB
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
FO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
2186.00000-
2186.00000-
.25720
.25720
.25720
.24214
.25720
.25720
.01071
.00763
.03150
.02568-
.00176-
.03150
.03150
.03150
.03150
.03150
1.90000
1.90000
1.9UOOO
1.90000
1.90000
1.90000
1.90138-
1.90000
27369.92598-
U90000
1.90000
1.90000
1.90000
1.90000
1.90000
1.90138-
1.90000
-------
MPSX-PTP13 EXECUTOR.
SECTION Z - COLUMNS
MPSX RELEASE 1 MOD LEVEL 3
PACE
41 - 74/165
NUMBER .COLUMN. AT
..ACTIVITY INPUT COST..
.LOWER LIMIT.
.UPPER LIMIT. .REDUCED COST,
1*5 WMCOA BS
153 W-CDfl BS
73? WM8DL BS
252 WMFON BS
253 UMGOM BS
755 KMAOO BS
768 WMFnP BS
269 WMGOP BS
297 WSMCOG BS
305 WSMCOI OS
3*0 WSMFDP BS
509 XMGONOA BS
717 XMGONOB BS
9'. 0 XI F OP OC B S
9*1 XWiO°OC BS
11*6 XMODPOO BS
1149 XMGOPDD BS
135* XMDDPDE BS
1357 XMGOPOF BS
156* XVFRPOF BS
"J 1565 X.4GO?DC RS
2} 1770 XMnnPor, BS
177V XVGDPDG BS
1978 XMDDPOH BS
19fil XMCnPOH BS
2186 XVOnPDI BS
7139 XMGOPOI BS
2396 X1FOPOJ BS
?397 XMGOPDJ BS
2581 XMcr,MOK BS
2589 XMGONOK BS
2fll3 XMGHPDl BS
30ia xunnpoM BS
302! XMGOPOM BS
3*37 X^GOPOn BS
3360 XMFOPDO BS
3861 XWGOPOO BS
*066 XXDOPDH BS
4069 XMGODDR BS
5732 XSMFOPHO BS
5776 YMCMCDA BS
5881 YMDPAOH BS
6591 SS10F BS
6592 SSI DC BS
6593 SSini BS
659* SS10J BS
6595 SS10L BS
6596 SS1DM BS
6599 SS2DF BS
47.632*3
33.12652
363.6*020
3130.20596
2177.58003
76.'82088
1388.30127
965.79509
* *
772.85*39
537.49036
333.67151
121.*8937
7*6.90933
1*8.67780
91*. 0621*
1610.66787
1120.49119
393.5*955
2*19.51926
3<>4.00*61
2422.31695
262.23091
1612.17970
1926.78737
1270.835«0
905.41152
629.86472
3*89.52175
191.55070
1177.6*208
10*9.9B387
852.02*76
592.72521
110.78630
681.10762
*
*
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NCNE
NONE
NONE
NOME
NONE
NONE
NONE
NPNE
NONE
NOME
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NOME
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
.
-------
yf>SX-«>TF13 FXFCUTOR. MPSX RELEASE I MOO LEVEL 3 PACE
NIJMBFR .COLUMN. AT ...ACTIVITY INPUT COST.. ..LOWER LIMIT. ..UPPER LIMIT. .REDUCED COST.
42 - 74/165
6602 SS20J
6601 SS7DL
6604 SS20M
660? SS?OP
6606 SS200
f>607 S10F
6609 S3DF
6610 SI Of,
6612 S30C
6613 S101
6615 S3DI
6616 SIOJ
6618 S30J
6619 S10L
6621 S3DL
6622 SI DM
6624 S-»DM
6625 SlOP
6627 S30P
6578 SI HO
6630 S300
6631 CC10N
6632 CC10P
to 6633 CClf-'A
0* 6634 CC1MB
*" 6635 CCl«1C
6636 ccno
6637 CCIPA
6638 CC1PB
6639 ClON
6641 C10P
6643 Cl^ft
6645 Cl^in
6647 CIMC
6649 CIMD
6651 CIPA
6653 C1»B
6666 ODL
6673 TPIT
6674 TFPT
6675 T4SH
6676 TSC1
6677 TSC2
6678 TWSH
6680 TSTO
6690 IN230F
6691 TN73DG
6692 IN230I
6693 1N230J
6694 TN21DL
6695 IN23DM
RS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
SS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS 171510
BS 232084
RS 2128
OS
BS
BS
BS 8120
IV
IV
IV
IV
IV
IV
51717 I
66238 1
46262 1
1
1
1
40130 1
00000
00000
00000
00000
00000
00000
00000
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NCNE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONC
NCNE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NCNE
NONE
NONE
NONE
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
-------
MPSX-PTF13
EXECUTOR. MPSX RELEASE L MOO LEVEL 3
PAGE
43 - 74/165
NUMBER . LULUMN.
6696 IN23DP
6697 IN2300
6698 IM120N
6699 IM120P
6700 TMI2MA
6701 TM12M8
6702 IM12XC
6703 fM12in
6705 IM12PB
A I . . . av. i i \
IV
IV .
IV
IV
IV
IV
IV
IV
IV
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
t
L_
0%
CO
-------
vo
Case 2: Spec. = 20 Ib SO2/MMBtu
-------
PAGE
39 - 74/212
kl 1 AIR CD
i
?
3
4
A «;
ft
7
ft
9
10
11
12
13
14
15
16
17
IB
19
to ?1
J 2?
0 23
24
25
26
27
28
29
30
31
32
13
14
35
36
37
\B
39
40
. 41
42
43
44
45
46
47
48
49
-.-.-.ROW,...
rOSTTOTL
fOSTPIT
-AT
BS
EO
--...ACTIVITV.-..-
318475. 250i4
-StAC*-ACT-IVJTV
318475.25054-
. -4_DUER LI MIT~»
NONE
..UPPER- L IMIT-.
NONE
COSTFRT EO .
CQSTASH EO
COSTSC1 FO
COSTSC2
COSTWSH
JCOSTR.EE_
COSTSTO
COSTBRN
AM A
AMB
AMC
AMC
AME
AMF
AMG
AMH
OD A
DOB
one
ODD
DOE
DDF
nor,
ODH
DO I
DOJ
DDK
DDL
DOM
DON
or>o
DDP
DDO
DDR
EDA
FOB
EDC
EDO
FOE
EOF
FflG
COM
EDI
EDJ
EOK
EDI
EDI
EO
EO
EO
EO
EO
BS.
BS
BS
BS
BS
BS
8S
BS
EO
FO
EO
FO
JEO
EO
FO
EO
EO
EO
EO
8650.43311
9499.41084
11383.36038
7097.99399
18634.00000
12994.00000
17726. OOOCO
20023.00000
24504.00000
59525.00000
64062.00000
64937.00000
43219. OOOCO
67512.00000
33461.00000
41349.56689
50000.00000
40500.58916
38616.63962
5000C. 00000
42902.00601
5000C. 00000
5COOO. 00000
EO 87C17. 00000
EO 31570. COOCO
EO 115682.00000
EO
EO
EO
EO
BS
BS
BS
BS
...us
BS
BS
BS
BS
BS
BS
BS
BS
25608.00000
51307. OCOCO
31488.00000
18259.00000
253180.45174
176077.22061
9195S. 86293
103876.35876
127123.12316
308606.88485
762474.61583
763356.26604
585645.79019
350242.25804
57328.97398
1179137.41006
427794.20154
120499.54826
83802.77939
262560.13707
296583.64124
362956.87684
881693.11514
53476!). 3U416
535383.73395
27d734. 20981
999997.74195
611891.02602
561202. 5B994
20J605.7S845
NONE
NONE
NCNE
NCNE
NONE
NONE
NCNE
NONE
18684.00000
12994.00000
17726.00000
20023.00000
24504.00000
59525.00000
64862.00000
64937.00000
43219.00000
67512.00000
33461.00000
87017.00000
31570.00000
115682.00000
25608.00000
51J07. 00000
31488.00000
18259.00000
NONE
NONE
NCNE
NUNE
NCNE
NCNE
NONE
NONE
NONE
NCNE
NGNE
NUNE
NONE
50000.00000
50000.00000
50000.00000
50000.00000
50000.00000
50000.00000
50000.00000
50000.00000
18684.00000
12994.00000
17726.00000
20023.00000
2A504.00COO
59525.00000
64862.00000
64937.00000
43219.00000
67512.00000
33461.00000
87017.00000
31570.00000
115682.00000
25608.00000
51307.00000
31488.00000
18259.00000
373680.00000
259880.00000
354520.00000
400460.00000
490080.00000
1190499.99999
1297239.99999
129H739. 99999
8643EO. 00000
1350239.99999
669220.00000
1740340.00000
631400.00000
nij AI ACTIVITY
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
29.29178-
l.OJOOO
1.00000
134358-
.34358-
.38662-
.43381-
.4U7J-
.39867-
.47599-
.47599-
.39444-
.39114-
.49105-
.39307-
.46043-
.36617-
. 32 67 6-
.3i725-
.38235-
.36561-
-------
.NPSX-PTF16. EXECUTOR. MPSX RELEASE 1 HOD LEVEl 4
NUMBER. ...ROW.., AT .. .ACT IVl TY. ... SLACK. ACT IV ITY . .IOWFRJJ MITj
PAGE
. .UP.PER. JLJLM IT. .DUAL ACTIVITY
40 - 74/212
A
A
A
A
A
A
A
A
A
I
A
A
N)
A
A
A
A
A
A
A
50
52
53
C A
55
56
57
58
59
60
61
62
63
64
65
66
67
68
69
70
71
72
73
74
75
76
77
78
79
80
Rl
82
83
R4
85
86
87
88
R9
90
91
92
91
94
95
96
97
98
99
100
EON
FOP
EDO
PHP
SIZXDF
SI7XDG
SI ZXDI
SIZXDJ
SI ZXDL
SIZXDM
SIZXDP
SIZXDO
F01PF
E01DG
E01DI
E01DJ
E010L
EOin.M
F01DP
F01DO
EOPOF
F02DG
F02DI
E020J
F02DL
E02DM
E02PP
E0700
E03DF
F_a3DC.
E03CI
E03RJ
EOTPL
F03PM
F03DP
F0300
F050F
F05Cf.
F.05DI
F05PJ
FOSOL
E05PM
E05DP
F05DO
F06CF
E06PG
E06PI
E060J
FQADL
F06DM
BS 198198.80960 2115441
BS 30103C. 64910 211129
BS 266173.11787 759966
BS 163355.08089 466404
BS 214640.68346 _150539
EO
EO
EO .
EO
EO
EO
EO
EO
BS
UL
UL
UL .
UL
UL
UL
UL
BS
BS
BS
BS
BS
UL
BS
BS
UL
BS
as
RS
BS
UL
UL
BS
BS 1
BS . 1
HS 1
BS . 1
BS . 1
BS 1
BS . 1
BS . 1
EO
EO
EO
EO
EU
EO
19039
35089
88213
91910
31654
00000
00000
00000
00000
00000
00000
00000
00000
NCNE
NONE
NONE
NONE
NCNE
NONE
NCNE
NONE
NCNE
NONE
NONE
NONE
NONE
NONE
NONE
NCNE
NCNE
NCNE
NONF
NONE
NONE
NCNE
NONE
NONE
NCNE
NONE
NONE
NONE
NCNE
NONE
NONE
NONE:
NONE
NONE
NCNE
NONE
NONE
2313639.99999
512160*00000 . .
1026140.00000
629759.99999
365180. QOOOO
*
'. 14473
*
2412
*
I 14473
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
1. 00000
16885
18274-
09965
18328
09965
26293-
-------
.MPSX-PTF16. EXECUTOR.
..NUMBER. ...ROIn_. AT. .
PPSX PELEASF I MUD LEVEL 4
.ACTIVITY.... SLACK ACTIVITY . .LOWE PJLI MIT ,
PAGE 41 - 74/212
.UPPER LIMIT. -QUA! ACTIVITY
A 101
A ..102-
103
A 104
a 105
A 106
A 107
1 08
A 'l09~
A 110
111
A 112
A 113
A 114
A 115
116
117
A 118
1 19
120..
fJ 121
>J 1??
W 123
124
1?5
_126
127
128
129
130
131
132.
133
134
1 3b
~136~
137
138.
139
140
141
142"
E06DP
E0600
HOF
HOG
HOI
HOJ
HDL
HDM
"HOP
HOO
.IOF
JDG
jni
JOJ
JHL
JDH
JOP
JDO
SIZYON
STZYDP
SI7YKA
SIZYMB
S I 7 YMC
SI ZYMD
SI/YPA
SIZYPB
E003HN
E003PP
F003MA
F003MB
F003MC
EOC3MD ...
P003PA
CQ03PB
FON
FDP" "
FHA
FMB
FMC
Fin
FPfl
FPB
EO
EO ..
EO
EO
EO
EO
EO
FO
FO
EO
EO
EO
EO
£0
EO
EO
EO
EO
EO
EO
EO
EO
FO
EO
EO
EO ..
EO
FO
FO
FO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
= 0
EO
.0<*76i-
.18274-
.03150
* '. .03150
.0315U
! * .3841
-------
.MFSX-PTF16. FXFCUTOR.
SECTION 2.- COLUMNS
MIMBFB- .COLUMN. AT
MPSX RELEASE I MOO LEVEL 4
PAGE
42 - 74/212
.ACTIVITY.,..
..INPUT COST.
145
153
191
199
709
733
741
252
255
766
_ 2 79
295
305
321
938
1146
1154
1562
7394
7«JB8
M 3 fl 5 8
*** 4766
W 4890
5306
5730
6162
6-517"
. 6689
6800
6801
6802
6801
" 6804
6805
6806
6807
6812
6R13
6815
t>B16
6819
6822
6875
. 6fl?8_
6830
6831 '
6831
6.134
6815
WHCOA
WMCCB
KM A DO
WMADH
WMCDI
WMCCL
WMCOM
WMFDN
MM A 00
WMOOP
WMAOR _
WSMAOG
wsicoi
WSMCOl
XMDOPDC
XMOOPDO
XMCDPDE
XMDDPnF
XMCOPD.I
XMFONOK
XMDOPnO
XSMOnPOF
XS.MDOPOJ
XSMCOPOM'
XSMODPDQ
YMODNOK
YSMRPBCF
YSMAMADM
SSIDG
ssini
SSI 0.1
ssim
SS1CM
SSIDP
SSIDO
SS2DF
SS20M
SS2UP
sinp
S2CF
52 OG
S2HI
S20J
S70L
sinw
s?nw
SI nP
S20P
S1DP
BS
PS
as
BS
BS....
BS
BS
RS
BS
BS
BS
BS
BS
BS
BS
BS
BS
as
as
RS
BS
BS
BS
BS
US
BS
BS
BS
BS
tiS
BS
BS
9S
BS
HS
BS
RS
HS
BS
RS
BS
RS
BS
BS
RS
as
BS
BS
BS
917.32129
637.96151
3230.82464
3234.56045
'2121.90691
4272.24077
1549.98036
5b05. 52249
1275.55360
2146.55740
909.49442_.
.
.
.
741.61180
837.71257
1025. U&48
2490.37810
2824.53434
1592.47150
"" 1317.37968
.
.
.
.
.
"
.
.
. "
.
.
.
.
.
.
.
.
.
.
.
.
.
.
" . ~
.
.
.
.
.LCWEP LIMIT. ..UPPER LIMIT. .BEDUCEI
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NCNE
NCNE
NCNE
NONE
NCNE
NONE
NONE
NONE
NCNE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NCNE
NONE
NCNE
NCNE
NONE
NCNE
NONE
NONE
NONE
NCNE
NONE
NONE
NONE
NONE
NONE
NCNE
NONE
NCNE
NONE
NONE
NONE
> COST .
-------
.MPSX-PTF16. EXECUTOR. HPSX RELEASE I MOO LEVEL
M1MBER .COLUMN. AT ...ACTIVITY^.. ...INP.UT CCST.,
..LOWER .LIMIT.
PAGE
_JLEJDU££D_C US T .
- 74/212
6836
6817
6dJ9
6840
6842
6843
.. 6844
6845
6846
6849
6P51
6851
6655
6857
6859
6860
68R1
6882
. _ 6883..
6885
6.Qfi6
6888
N) 6889
~J 6390
* 6891
6P92
6893
6894
6995
6898
6499
6900
6901
6902
6903
6904
6905
6906
6907
6908
6909
6910
691L
6913
sino
5200
CC ION
Cf IDP
rCIMB
CCifC
CCli^O
CC1PA
cr. IPB
ctnp
C1MA
C1MB
C1MC
C1MO
ClPfi
C2PA
TPIT
TFRT
TASH
TSC2
TMSH
TSTD
T3PN
IN12DF
IN12HG
IN12DI
IN120J
TN12DL
IN12DM
IN? JPF
IN23DG
IN2301
IN230J
TN230L
n23l)M
IN23DP
IN23DO
IM12PN
IM120P
IMl?MA
IM12MB
IM 12MC
IM12MD
I.M12PR
BS
BS
BS
as
BS~~
BS
BS.
BS
BS
as .
BS
as
BS
as
as
BS
HS
BS
BS_.
BS
BS
BS
BS
IV
IV
IV
IV
IV
IV
IV
IV
IV
IV
IV
IV
IV
IV .
IV
IV
IV
IV
IV
IV
IV
»
.
.
*
.
_ .
.
.
_.
.
.
.
.
.
.
2~1 951 6." 61 397
90935.21831
._ .4774.6359^
.
.
3248.78234
.
.
.
.
.
.
.
.
.
.
.
.
.
.
.
.
.
. __ _^__
.
.
.
.
1.00000
1.00000
._ 1.00000
1.00000
1.00000
_I.00000
1.00000
NONE
NONE_
NONE
NCNE
_NONE_
NONE
NONE
NCNE_
NONE
NONE
NONE_
NCNE
NCNE
NCNE
NONE"
NCNE
NONE
NONE"
NONE
NONE_
NONE
NONE
NONE_
NUNE
1.00000
_1.00000
1.00000
1.00000
1.00000
1.00000
_1.00000
i".oooo
-------
U1
Case 2: Spec. = 5 Ib SO./MMBtu
£
-------
10 - 74/164
JI-L I 1 J'M
NUMBFP
i
4
5
6
7
fi
10
11
12
13
1 4
15
16
i 7
18
19
20
10 21
-J 22
tf> ?3
?5
26
77
.78
30
32
~" 33
35
36
37
23
"39
40
41
42
43
44
45
47
48
49
I - ^ uw >
. . .ROVr. .
COSTTOTL
COSTP IT
COSTASH
COSTSC1
COS1SC2
COSTWSH
COSTPFF
C..1STSTO.
AM 4
AMB
A -1C
AVID
if E
AMC,
nnA
DDB
onr
nnn
onfc
noc
nnH
no i
onj
00 K
ODL
OHN
nun
no?
000
EHA
C03
FOE
'EOF" "
EOT
FOH
rc i
FOJ
EOL
AT
BS
FO
FO
F.O
F.O
FO
EO
FO
EO
eo
BS
BS
HS
BS
flS
BS
EO
FO
EO
FO
EO
FO
FO
FO
<=0
FO
FO
FO
EO
FO
EO
EO
UL
UL
UL
UL
UL
UL
UL
in
UL
UL
UL
. ..ACTIVITY...
358183.05216
508.37364
2406.44351
534.43454
19741.47072
7603.51512
3813.71776
18684. OOOCO
12S94.0000C
17726. OOOCO
20023. OOOCO
245U4. CCOCO
59525.00000
648IS2. 00000
64S37. COCCO
4321°.OCOCC
67512. OOOCO
33461. OCOCO
87017. OOOCO
31570. OOOCO
115632. OOOCC
25608.00000
51J07.0000C
31488. OCOCO
18259. OOOOC
9 342'j.OOOOC
64S70. CCOOO
"P630. OOOCO
10C115. CGCUO
12257C. OCCCC
29"7625'.OOOOC
32431C.OCCOC
324685. CCCOO
?ltC95. COOOO
33 1560. CCOCO
57323. g?}^
-'3 503 5.00000
157bSO. COOOO
SLACK ACTI VI .'Y ..
350183.05216-
-
49491.62636
47593.55649
49465.56546
30258.52128
5000C. 00000
316.48438
41u6.2R224
*
1C9976.0260?
.LOKEO LIMIT.
NON«=.
-
*
NONE
NONE
NONE
NOME
NCiNE
NGN?
NCNF
14684.00000
12594.00000
1 7726. COOOO
20023. JOOOO
24504.00000
59525.00000
6 4 P6 2. 00000
64937.00000
43219.00000
67512.00000
33461.00000
87017.00000
3157C. 00000
11 56 12. 00000
25608.00000
51*07.00000
31488.00000
18259.00000
NONE
NCNE
NGiNF
NONE
MONF
NONb
NCNE
iNONF
NHNE
NJNE
NONE
'MINE
..UPPER LIMIT.
NONE
50000. COOOO
50000.00000
50000.00000
50000.00000
50000.00000
8300.00000
. POOO. 00000
18684.00000
12994.00000
17726.00000
20023.00000
24504.00000
59525. OOCOO
64862.00300
64937. OUOOO
43219.00000
-S7512. 00000
33461. COOOO
87017.00000
31570. COCOO
115682.03000
25608.00000
51307.00000
31406.00000
16259.00000
93420.03000
64970.00000
3H630. 00000
100115.00000
122520.00000
2^7625.00000
324310. O'JCOO
324685.00000
216095.00000
337560.00000
167305.00000
435035.00000
157850.00000
.DUAL ACTIVITY
l.OOuOC
l.ouuoo
1 \J\j u o 0
1 OL* -J J 0
l.OJUOO
.91 JOG
. 740VU
l.OJOOO
.0-.-7
! 66/5 3-
:EH:
.5V736-
. 5*736-
.£.fc,7i-
. 4v U 5-
.ioo!7-
.4-VJ4V-
,4o j74-
:%:l\
^02127
.Oil 09
.02U4
.02174
.020,0
.02305
-------
MPSX-PTF13 EXECUTOR. MPSX RELEASE I MOD LEVFL 3
NUMBFR RDW.. AT ...ACTIVITY... SLACK ACTIVITY .
50
52
53
54
55
56
57
58
59.
60
M
67
63
' 64
65
A 66
A 67
A 68
69
A 70
71
72
EDN
FDP
to*
SIZXDF
SIZXOG
sizxni
SIZXDJ
SIZXDL
SIZXDK
SIZXDP
stzxoo
E01HF
F.OIDG
EOlUt
FOinj
EUIDL
C0 1 O.M
EOIT.P
=01 DO
E070F
FQ2BG
.^ 73 E07DI
>j 74 CQ20J
-J /5 E02TL-
76
77
78
79
no
Rl
82
33
84
B5
86
87
Rfl
8V
90
91
9?
. 93
94
95
9ft
99
F020M
PQ2TP
E07DO
F03DF
E03DG
E03CI
E03n.l
E030M
E03DP
FQ3DO
E05DF
F050G
F05PJ
E050L
EOS CM
F050P
E05DO
E06DF
FOfcHG
F060I
E06HJ
BS 196iyB.0096C
III 12Q04Q.OOCCO
UL 256b35. 00000
UL 15744C. 00000
Ul 91295. OOOCO
EO
EO
FO
EO
EO
FC
EO
EO
BS
BS
BS
UL
UL
UL
UL
UL
as
BS
UL
UL
BS
UL
UL
Ul
UL
UL
BS
BS
BS
BS
RS
BS
BS
n.s
BS
BS
as
BS
BS
BS
EO
EO
EO
EO
EO
380211.19039
*
1.00000
1.0000.0
l.OOOOC
t.ocooo
1.00000
1.00000
1.00000
I. 00000
.
.LCWER LIMIT.
NONE
NONE
NCNE
NONE
NONE
NCNE
NONE
NONE
NONE
NONE
NTNE
NONE
NONE
NCNE
NONE
NONE
NCNE
NONE
NONE
NONE
NCNE
NCNE
NCNE
NPNE
NONE
IMLNE
NONF
NONE
NCNE
NONE
NONE
NONE
NPNE
NuNE
N'JNIE
NCNE
NONE
.
..UPPER L IMIT.
578410.00000
128040.00000
256535.00000
157440. COOOO
91295.00000
*
"
1.00000
1. COOOO
1.00'JOO
l.OOJOO
1.. 10000
1.00000
1.00000
1.00000
PAGE 19 - 74/164
.DUAL ACTIVITY
.02221
.01993
.0219*
12*720
.24214
.07o41
.24^14
.17617
.24214
9289.2JUOO
*
23B4.7..727
2384.72727
2384.72/27
322V.2UUUO
2384.7<;727
2186.00JOO
2186.00000
*
2186.0JJOO-
2186.00JOO-
2384.72727-
2384.72727-
100 F06DM
FO
2384.7*727-
-------
MOSX-PTF13 EXECUTE. MPSX REIEASF. I "00 LF.VF.L 3
NUMBCR ...ROW.. AT ...ACTIVITY... SLACK ACTIVITY
LIMIT.
CAGE
.UPPFR LIMIT. .DUAL ACTIVITY
20 - 7W164
N)
CO
A
A
A
A
A
A
A
A
101
102
103
104
105
106
107
103
109
110
11 1
113
115
116
117
118
119
120
122
123
124
125
126
127
128
179
130
131
132
133
134
135
136
137
139
139
140
141
14?
E06RP
EOftOO
HD«=
HOG
HOI
HOI
KIM
HOP
HOO
JDF
.IOC
J01
JOJ
.101.
JDM
jnp
.mo
SIZYDN
SIZYOP
SIZYMA
SI ZY»B
SI 7YMC
SIZYMD
SI7YPA
SI7.YPO
E003DP
F003MA
Foo3;--,a
FO03MC
F003PA
F.003PB
FON
COP
FMA
FMB
FMC
pwn
FPfi
FP8
EO
FO
FO
EO
EO
FO
EO
FO
EO
EO
FO
FO
FO
EO
FO
FO
EO .
EO -
EO
PO
FO
EO . . .
EO
EO
EO
FO
to
EO . .
EO
EO
to
FO
EO
EO
FO
FO
FO
FO
EO
EO
12518. 4UJJO-
238^.72727-
/* *t <2 i 4
^0 D J 3
.0/041
.17617
.00524
is;";i
*U^U<>6-
. 02 6J 3
1.41V12
1.4191*.
1.41V12
1.4191..
1 . 4 1 9 1 £
*
*
1.41912
1.41912
U41912
1.41V12
l.41Vl^
-------
MPSX-PTF1
SFCT ION 2
NIIMBFB
145
252
255
766
305
VU
329
339
509
717
940
1146
1149
1354
1357
In 177(1
1773
1978
21 «<,
?3'J4
2396
2813
30 1 P.
30 ?1
3437
3R58
3360
40">°
4771
5730"
5737
6715
6799
ftriOO
sr.oi
"6SU3
6804
3 FXFCUTOR.
.COLUMN.
wKcna
HMFHN
WMC.OP
WSMRDL
XKcirNDe
XMDPPDC
XMFDPOC
XMCPPOO
X^GDPOP,
"XMOOPDE
XHUDPDF
XMPCPDG
XMGPPDG
X-'DDpriH
XMGDPDH
X"GDPCI
XMDRPPJ
Y V f* P D P 1
x ^ m P o M
XfGPPnn
XXDDPOO
XMFDPDO
XSMADOTF
SSICL"
ssinH
AT ..
BS
PS
RS
BS
HS
riS
ns
RS
BS
BS
RS
BS
BS
HS
BS
BS
BS
BS
BS
BS
BS
BS
HS
as
HS
RS
BS
RS
as
BS
&S
BS
BS
BS
BS
BS
MS
BS
BS
BS
BS
US
RS"
BS
rtS
BS
RS
KPSX RELEASE 1 MOD LFVEL
.ACTIVITY INPUT CTST.
31b. 21482
2*06.44351
5505.52249
b08. 373ft4
2030.50J37
132.01616
535.06565
372.11748
701.51642
45.61C12
803. 97414
35.16304
903.89763
43.05784
2*55. 73534
153.16159
2604.37349
11J.973S6
2607.30493
114.10575
1735.35225
75.94J4J
2671.<)2536
173.71265 .
"~15~92. 47150
1764.72641
12fc7. 61541
55.47405
671.985C1
1?46.1553C
81.02062
733.14507
32.06428
- - - *- *- -
PAGE
21 - 74/164
..LChEK L!i»IT,
.UPPER LIMIT.
.REDUCED CiJST.
NONE
NQN!i_
NONE
NONE
N_PNE_
NONE
NONE
NONC_
NONE
MONE
NONF.
NONE
NONE
NOJ>IJ_
"NONE
NONE
NONE
NONE
NONE
NO\'E_
NONE
NONE
NlONE
NONE
NONE
NONE.
\ON"E "
NONF
T'ONE
NONE
NONE
MO.NE_
NONE
NONE
NONE
NCNE
NONE
NONF_
NONE
f.ON!J-_
VONE
MONE
NON^
NONF
NUNE
NJNE
«|ijNC
NONF
-------
MPSX-PTC13 EXFCUTPR. MPSX RELEASE I M3D LEVEL 3
.CHLUKN. ftT ...ACTIVITY INPUT CCST..
PAGE
22 -
6P05
6808
6B10
6 fill
6)315
ISS17
6. 9 IB
6921
6824
6^26
6830
6834
6835
"693'.
6R42
£ 6P/'3
Q 6 B44
6845
6B46
6850
6857
6P56
oS5<3
6861
6874
f,S81
6F8?
iSBBl
6034
6897
6RPP
6HV3
6995
6fi>J6
f).1.1??
6.T9S
fcr;oo
SS1CP
SS2DG
S30F
S1PP
S3DG
S10I
S10J
S3nJ
S10M
S3CW
SI OP
S20P
S_3HP
cr. inN
CC 1 HP
CCIMA
CC1MB
CC IMC
rci^n
CCIPA
CC1"R
cirw
Cl*i«
Cl^c
' cr-'-n""
riPB
001
TP IT
TF3T
TASH
TIC I
T^TC
IN12CJ
IM1POL
IMl?OM
I.\'12DP
IN23HG
I \23PT
BS
ns
BS
3S
BS
BS " ~" '.
BS
BS
BS
SS
BS
BS
BS
BS
BS
BS
BS
"B~S
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
B?
BS
BS ~ ~."
BS
BS
BS
BS 20516-5. 08274
BS 141748. 937t?
BS 41S7.i:JO«O
BS
S3
US 7071.2C067
IV
"IV "" " .
IV
IV
" IV
IV
IV
IV
.UPPER LIMIT. .REDUCED CuST.
N7NE
\C1NE .
,00000_
,"onooo
,00000
. ooo'oo"
i.ooooo
riONF
NONE
NONE
NCiNE"
MONT
NONE
NCJNE
NONE
NONE
NONE
_
' N'JNE
N-7NE
NCA'E
NCNE_
NL'NE
NONE
NONE
MJNE
NONE
_ _
Ni'.NE
JHME
1.03JOO
l.OJOOO
.oooqp
.~o "
1.00000
TCOOOTT
NONE
NONE
N'JNE
WJ.ME
NONE
NONE
NPNF
NONE
NCNE
NPNE
r'L'NE
-------
MPSX-PTF13
_ Ml J v, n F P _
EXFCUTOR. MPSX PFLEASE I MOD LFVEL 3 PAGt
A T . _. iACIW I_T Yj..... _ ...l^P U T_ COST ._. _ .^.L G_W FR LIMIT. ..UPPER LIMIT. .^FPUCEP C US_T_. _
23 -
6901 IN730J
690? IN23PL
6903 IN23DM
6905 IN73DQ
f>906 IM12DN
6907 !\'12DP
690B !M1?MA
A909 IMJ2M8
6910 IH12MC
691? IK12PA
6913 IM12PR
!V
IV
IV
IV
IV
IV
IV
IV
IV
TV
IV
.
.
.
.
1.00'JOO
i.ooooo
1.00000
1.00000
1.00000
1.00000
1.03000
1.00000
1.00000
1.00000
1.00000
to
CO
H
-------
Case 2: Spec. = 3.1 Ib SO,/MMBtu
co
to
-------
MPSX-PTF13 EXECUTOR. MPSX RELEASE 1 MOO LEVEL 3
SECTION 1 - ROWS
PAGE
22 - 74/164
NtJMflFR
1
2
3
4
5
6
7
8
9
10
11
12
13
15
16
17
ia
19
20
-------
MPSX-PTF13 EXECUTOR. MPSX RELEASE I MOD tJSEL 3 PAGE
NUMRFR ...SOW.. AT ...ACTIVITY... SLACK ACTIVITY "..ICWER LIMIT. ..UPPER LIMIT. .DUAL ACTIVITY
23 - 74/164
50 FDN
51 EDO
52 FOP
53 EDO
54 EDR
55 MZXDF
56 SI7XOG
57 SI7XOI
58 sizxnj
59 SIJXOL
60 MZXOM
61 SIZXDP
ft2 5IZXDO
63 C01DF
64 EOinG
65 EOin
66 CQJDJ
67 F01DL
68 F-01DM
69 E01DP
70 F01TO
71 EQ7CF
7? E02nR
.to 73 E92DI
00 74 F0?nj
^ 75 E02P-L
76 tQ?Cfi
77 EO?nP
78 F02DQ
73
. Ob oO 5
.2'V944
.30^13
.3060V
I3J13V
.30574
2187.60^03
2385.2t3Uo-
290.44651
2846.4179*/
B14.8j
-------
MPSX-PTrlJ
Fxrcurnp. MPSX PELEASE i MOO LEVEL 3
MUMPER ...RCW.
AT
.ACTIVITY.
SLACK ACTIVITY ..LCHER LH"IT.
PAGE
..UPPER LIMIT. .DUAL ACTIVITY
101
102
103
104
105
106
107
ion
109
110
111
112
113
115
116
117
110
119
121
122
CO 125
01 126
A 1?7
12B
A 129
A 130
A 131
A 13*
J35
137
M3
139
140
141
RJ6CP
F06HO
HOP
HOG
HDT
HOJ
MIL
HOM
HOP
HDO
.IDF
JOG
JDI
JDJ
.IOL
JOM
JPP
JDO
SI7YDN
SIZYOP
SIZY.IA
SI ZYMB
SI ZYMO
SIZYPA
SIZVPB
F.0030P
F001KA
F003:iB
FOO?MC
F003MO
PQ03PA
SOC3PB
FDN
FHP
PMA
FMD
FMC
FMD
EO
EO
EQ
EO
EO
EO
EO
EO
EO
EO,
E'O
EO
ro
EO
EO
EO
EO
FO
FO
ro
EO
EO
FO
to
EO
FO
to
EO
EO
EO
EO
EO
EO
EO
EO
EO
FO
EO
EO
EO
FO
205.61880-
161.8369;
.30313
.30009
.33139
.30374
. 2S>TbJ
.031 bJ
-OjlbO
0^ I t>O
O^l^O
.03130
.031'jO
-OoLio
1.90JJO
1.90JUO
1.9JOOU
2.0vJo:>l
1 *?U w 0 O
I. Oo ^ 1 /
: : : 70917:2193,
25562.90060
1.9JOOO
2.19544
. . 1.90000
1.9OOOO
l.oOOuO
142 FPB
EO
1.0641 I
-------
PAGE
25 - 74/16*
SfcL I I UN
NUMBER
250
25'
254
266
268
320
318
509
717
938
940
1146
1149
1354
1307
1565
1770
1773
1978
7394
2396
23<»7
e. in i linn:
.COLUMN.
WMDON
WMFHN
WMHDN
WMOCP
WMFnP
WSM60L
US MOO P
XMROPOC
XMf.OPDD
XMODPDF
XMfiDPOF
XMDDPOG
XMOOPDH
XfiCOPOh
xTirjpOT
XMfCPOI
X-.DOPDJ
XMFOPD.I
2536 XMTCNRK
25E3 XV^PNDK
2813 XMrr.PDL
3018 XMnnPDM
3021 XVGOPOM
3437 xMnnPon
3858
38'.0
4066
4069
4266
4474
4390
5306
5730
5775
5315
5917
6087
u2L5
6335
6387
XMDOPOO
SSSSKp
XSKOOPDJ
YMRhBDA
YHTiMBOB
YMBMBOL
YHPKBDO
AT
BS
8S
BS
BS
BS
RS
BS
BS
RS
3S
JLS_
BS
BS
BS
BS
BS
BS
BS
BS
BS
riS
BS
as
RS
BS
B.S
RS
BS
BS
ns
BS
BS
RS
BS
BS
US
BS
BS
RS
BS
BS
RS
BS
BS
BS
BS
BS
...ACTIVITY INPUT COST..
1931.58497
3308.26636 .
856.69138
1467.274R4
125^32999
87.1621t
295.97757
506.92698
462.73165
391.04675
566.28752
478.56019
1375.622S3
1162.51616
1498. 960S6
1266. /4719
150U. 63421
1268. 2H<53
<59f. 7^111
U44.06171
1367.33320
660.123H8
731.11232
55P. 71045
S56. 91573
503. 69958
729.56253
616.55861
171.77579
525.766311
900.49219
271.68670
273.21761
927^90241 !
645.32027
4321.5200C
1271.76801
..LCWER LIMIT. ..UPPER LIMTT. .PE.CUCED COST.
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONF
NUNE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NON E
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE .
NUNE
NONE
. NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
-------
MPSX-PTF13 EXECUTOR. PPSX RELEASE 1 MOD LEVEL 3
NUMBER .COLUMN. AT ...ACTIVITY INPUT CC'STl. ..LOWER LIMIT. ..UPPER LIMIT. .PEDUCED COST.
26 - 74/164
6455
6799
&800
6801
6302
6803
6804
£,805
6906
6807
5803
6009
6810
6811
681?
6813
6814
6P16
6C17
6818
6319
6820
6821
10 6372
TO 6323
-J 6825
6826
6828
6829
6831
68^2
6834
6835
6837
68^9
6840
6841
6842
6843
6845
6846
6847
6850
6851
6R53
6854
6855
6851
6859
YMBKBCR
SS1TF
SSICG
SS10I
SS10J
SS10L
SS 1 HM
ssinp
SSI DO
SS2DF
SS?OG
"SS2CI
SS2DJ
SS2CL
SS2DM
SS2DP
SS?DO
S?.OF
S30F
si or,
S20G
S3DG
SIDT
S2CI
S3CI
S2D.I
S3DJ
S2DL
S3CL
S2DM
S30M
S20P
S3HP
S2HQ
S3DO
CC1TN
CC1HP
CC1MA
CCIMB
CC1MC
CC1KO
CCIPA
CC1PB
C10N
C70P
C1MA
C2MB
C1MC
C2MO
C1PA
BS 322.94636
BS
BS
BS
BS
BS
RS
6S
BS
BS
RS
BS .
RS
BS
BS
BS
BS
BS
BS
BS
RS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
bS .
BS
BS
RS
PS
BS 7489.45706
BS
BS
BS
BS
BS
BS
BS .99876
3S .00124
BS
BS
BS
NONE
NCNE
NONE
NONE
NONE
NONE
NONE
NONE
NONE . '
NPNE
NONE
NOME
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NON E
.NONE
NONE
NONE
NON E
NON E
NONE
NONE
NONE
NIJNE
NONE
NPNC
NCN E
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NON E
NONF
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
-------
PAGE:
Z7 -
NOMBFR
6861
6874
6BP1
6832
6881
6884
6885
6ft36
6837
6883
6908
A 6909
6410
6912
.COLUMN.
C1PB
COL
TPIT
TFRT
TA SH
TSC1
TSC2
TW SH
TREF
TSTO
IM12PN
IM17MA
IH12MB
IM12MC
IM12PA
AT
BS
"BS
BS
BS
BS
BS
BS
BS
BS
IV
IV
IV
IV
IV
. . .Ol. 1 IV 1 1 T. . ..IT-
207109.93302
16C788. 41117
3355. 53245
14229.96841
464. V«634
8659.81841
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
j.nnnoo
l.OOOCO
1.00000
NONE
NONE . «_
NONE
NONE
NONE .
NONE
NONE
NONP
NL'NE
NONE
1.00000
1.00300
1.00000
l.COOOO
1.00000
10
00
-------
to
so
V£>
Case 2: Spec. = 1.2 Ib SO2/MMBtu
-------
PAGE
53 - 74/163
I COSTTHTl
2 COSTPIT
3 COSTFRT
4 COSTASH
5 C.'JSTSCl
6 CCJSTSC2
7 COSTWSH
8 COST1FF
9 cnSTSTfl
10 CHSTBRN
11 AM A
12 A"H
13 A'-«C
14 AM C
15 AME
16 A« P
17 AMf,
18 AMH
19 Of! A
70 010
£ 21 DOC
o 7? noo
23 HOE
74 OOF
75 DOG
27 OOt
?F DO.)
?9 DDK
30 DHL
31 DDK
32 Dr>N
33 mrj
1* nn p
is nno
36 1)05
37 PDA
T3 FRO.
39 EHC
40 Fnc
41 EOF
47 EOF
43 PDG
4 /, f n j-
45 FOI
46 FO J
47 fV
48 Ei"1!
'.9 crjM
AT
BS
FO
EO
EO
FO
EO
EO
FO
EO
EO
US
BS
BS
BS
BS
ill.
UL
UL
EO
EO
EO
EO
EO
EO
EO
FO
FO
EO
FO
FO
FO
FO
EO
FO
EO
UL
UL
UL
UL
UL
UL
UL
UL
UL
UL
UL
UL
UL
. ..ACTIVITY...
525112. 38300
4171.04132
14S02. 69477
8000.00000
8000.00000
186R4. 00000
12994.00000
17726. OOOCO
20C23. 00000
24504. COOCO
59525. OOCCC
64862. 00000
64937. CCOCO
43219. OOOCC
67512.00000
33461.00000
87C1 7. COOCO
31570.00000
115682. OCCCC
75608. OOOCC
51207. OOCOC
18259. OOOCC
2242C. 79297
1 5E92. 79688
21271.19531
24027.59375
294U4. 79297
7142S. 93750
77834.37500
77974. 375CO
51E62.739C6
81014. 375CO
4C153. 191 41
104*20. 375 00
37683.99219
SLACK ACTIVITY ..LOWER LtfMT.
525112.38300- NONE
5000C. 00000 NONE
45828.95868 NCNE
50000.00000 NCINE
35097.30523 NCNE
50000. 00000 NONE
NCNE
NCNE
NONE
18684.00000
12994.00000
17726.00000
2C023. 00000
24504.00000
59525.00000
64862.00000
64937.00000
43219.00000
67512.00000
33461.00000
87017.00000
31570.00000
115682.00000
256C8. 00000
51307.00000
31488.00000
18259.00000
NCNE
NCNE
NCNE
NCNE
NCNE
NONE
NONE
NCNE
NONE
NCNE
NPNF
NONE
NONE
..UPPER LIMIT.
NONE
sooooiooooo
50000.00000
50000.00000
50000.00000
50000.00000
8000.COOOO
8000.00000
18684.00000
12994.00000
17726.00000
20023.00000
24504. CCOOO
59525.00000
64862.00000
64937.00000
43219.00000
67512.00000
33461.00000
87017.00000
31570.00000
115682.00000
25608.00000
51307.00000
18259.00000
22420.79297
15592.79688
21271. 19531
24027.59375
29404.79297
71429.93750
77834.37500
77924.37500
51862.78906
81014.37500
40153.19141
104420.37500
37803.99219
.DUAL ACTIVITY
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
l.OUUOO
1.000UO
.00010
4.36601
6.63264
2.26113
.98854-
.93854-
.82114-
.86839-
.84828-
.80715-
.89309-
.91924-
.96220-
.79962-
.86070-
.86435-
.95400-
.75079-
.90966-
.76573-
-79084-
.94379-
.08431
.08431
.09158
.08782
.08942
.07874
.07874
.08378
.07874
.07874
.09449
.05U07
.07874
-------
MPSX-PTF13
EXFCUTCJR. MPSX RELEASE 1 KCD LEVEL 3
PAGE
54 - 74/163
NUMBER ...ROW
AT
...ACTIVITY... SLACK ACTIVITY
.LOWER LII*IT. ..UPPER LIMIT.
DUAL ACTIVITY
50
51
52
53
54
55
56
=.7
58
59
(SO
61
63
66
59
70
71
7?
ro 73
VD 74
H 75
76
77
78
79
80
.Tl
82
33
34
35
R6
37
88
39
-------
MPSX-PTF13
EXECUTOR. HPSX RELEASE L MOO LEVEL 3
PAGE
55 - 74/163
MJI"RCP
.ROW.
.ACTIVITY.
SLACK ACTIVITY
L1VIT. ..UPPER LIMIT. .DUAL ACTIVITY
NJ-
VO
A
A
A
A
A
A
101 F06HP
102 F0f.no
103 HOP
104 l-DG
105 HOI
106 HOJ
107 HDL
lOfl HPK
109 HOP
110 mo
111 JDF
n? JDC
113 JOI
114 JO.I
115 JIU
116 JDM
117 JQO
llfl JOC
ll'y SIZYON
120 MZYDP
121 SIZYMA
122 SIZYM8
_.12.3 SIZYMC
124 SIZYMD
125 S'/YPA
Ud MZYPP
127 FQ01CN
12R F0030P
1?9 F003MA
730 F003NB
131 C003MC
1 3? POO^wrj
133 F.OOTPA
134 F003PB
135 FOM
136 FOP
M7 FMi
138 F,M B
I3<5 FI^C
140 FMD
141 FPA
14? FPfc
l=Q
EO
EO
FO
FO
EO
EO
FO .
EO
EO
FO
FO
EO
EO
FO
EO
EO
EO
EO
EO
EO
EO
EO
EO
EO
FO
EO
FO
FO
EO
EO
EO
FO
FO
EO
FO
EO
FO
EC
EO
2017.20000-
2017.20OUO-
.2o998
.26998
.2694U
.26998
.218V4
.26998
.26V9b
.26996
.03150
.03150
.031SO
.03150
.OJ15U
.03150
.0315U
.03150
1.90000
2.05e40
1.900UO
2.5J627
1.90000
1.90000
1.90000
37535. 61611
152703.69041
1 1 1^90000
2.05640
. 1.90000
1.90000
1.90UOO
1.90000
1.90000
-------
MPSX-PTF13 EXECUTOR.
- COLUMNS
MPSX RELEASE 1 MOO LEVEL 3
PAGE
56 - 74/163
252
754
768
37U
338
508
509
716
717
940
1148
1 140
1356
1157
1770
1 97R
£ ljj£
?394
2PIO
3Cl«J
3436
1437
3858
4066
4069
4766
4474
'.63?
4(1<30
5730
6715
6447
6799
6800
6801
.CTLUMN.
VsMFON
W.-IGTN
'..'.MDDP
WM F r.f>
VSNfbDL
WSMOOP
XIK.UNDA
XMrnNDB
XVFOPOC
x^r.ipoc
XMFDPCO
XMGDPHE
xMODpnr,
X'-IFOPOH
X'GDPOH
X^TCPPI
X.MPONOK
XVT.DMOK
x'-iFrpnn
X^OOPDO
XXCOPPR
XVGDPCR
XSM50PDF
~x"sKni)?of
XSMDOPOJ
XSHCOPHN
XSMDDPOC
YMB^BOL
SSI OF
SStPT
680? SS1DJ
6R03 SS1DL
6804 SS1DM
6SOS
6R06
SS1PP
SS1DO
AT
BS
BS
BS
BS
dS
BS
BS
BS
BS
ns
PS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
liS
BS
BS
BS
BS
BS
RS
as
BS
RS
BS
BS
BS
BS
flS
IS
BS
RS
BS
SS
BS
BS
...ACTIVITY...
3130.20596
2177.56CC3
202*.0fl412
493.97842
4171.04132
1510.22200
505.56486
351.7C483
351.6C090
244.597C5
479.64270
333.671bl
541. 7S652
376.9C592
663.04662
461.25956
363.34477
395.92258
341.12275
235.H3302
2261.26372
263.81211
412.09839
SOS. 41152
fc?1;. 86472
263.536M
192.7C572
692.91948
482.041C5
192.20520
110.78630
681. 10762
2127.03333
2317.74234
1544.36346
2412.43'.95
1 128. 10464
1125.17448
5CC4C. 33578
55398.66123
57662.02712
V' 80717.94983
26S63. 94922
V. 36C97. 31574
26693.91266
..INPJT CCST.. ..LChEF LIMIT. ..UPPER LINIT. .REDUCED COST.
NONE
NONE
NONE
NONE
NONE
NONE .
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE .
NONE
NONE
NONE .
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
-------
MPSX-PTF13
EXECUTOR. MPSX RELEASE 1 MOD LEVEL 3
PAGE
57 - 74/163
6007 SS7CF
6803 S52or,
6809 SS2DI
6810 SS2D.I
6811 SS2DL
6812 SS?G.*
6313 SSPDP
6314 ss?no
6015 SIHF
6ftl6 S20F
5817 S3DF
6618 S1HG
6819 S2DG
63?C S3PG
6821 Sini
6822 S2DI
68?3 ST1T
6324 S1DJ
6825 S23.I
6826 S30J
fc828 S201
6329 S3DL
^130 SI DM
NJ 6031 SPrv
** 6H32 S^HM
S033 Sl^lP
6334 S20P
6«35 S3HP
68J6 SI DO
6337 S700
6838 S300
6839 r.ClDN
6840 CC1PP
6841 CCIMA
6043 CC1MC
^<144 CC1MD
6846 CC1PD
6847 CIDN
6RS4 f?*1B
^855 CIMC
6H58 C.?W
6P59 CIP4
68l»l C1PP
Alift3 QCfl
6P32 TCRT
BS
BS
BS
RS
BS
BS
BS
JS.
BS
RS
BS
ns
RS
BS
BS
BS
BS
BS
RS
BS
BS
BS
BS
BS
BS
BS
BS
BS
ns
BS
RS
BS
BS
RS
bS
BS
RS
BS
RS
RS
BS
BS
RS
BS
RS
BS
BS
BS
BS
1576C4. 90628
171735.70311
114431.33277
178752.13136
347067.01326
835P8. 17118
1 1 1901.58321
83J71.05BQ3
.42969
.57031
.36063
.63937
.64071
.35929
.32633
.67367
.9 '-083
.01917
.7°146
.20854
.65307
.34693
.79252
.20748
.
'.
.
.
.
1^9517.06321 1.00000
15S1J3. 35653 1.00000
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONF
NONE
NONE
NONF
NONE
NONE
NONE
NONE
NONE
NONF
NONE
NONE
NONF
NONE
NONE
NHNF
NONE
NONE
NONF.
NONE
NONE
NONF
NONF
"
*
"
'
'
-------
MPSX-PTF13 EXECUTOR. KPSX RELEASE 1 MOD LFVEL 3 PAGE
.COLUMN. AT ...ACTIVITY... ..INPUT COST.. ..LOWER LIMIT. ..UPPER LIMIT* .REDUCED COST.
58 - 74/163
6P33
..*p84_
6035
OR^'i
6P17
A.Irtp"
6890
_
6H92
6893
6V02
690ft
690P
691 5"
691T
TASH
TSCI
T,JSH
TPPF
TSTD
1N12DF
IM17T,
TNl?OL
IN120P
l_NJ2nQ_
'Ml?/ A
1'1 l?PA
SS
BS
ns
HS
BS
IV
IV
IV
IV
IV
IV
IV
IV
IV
IV
IV
IV
IV
IV
3762.39461 l.OCOOO
116356.11636 1.00000
39326.86482 1
i
1
7C16.5R727 1
1.00000
1.00000
l.OCOOO
l.OOOOG
1.00000
1.00000
1.00000
i.ooooo
00000
00000
00000
00000
NONE
NONE
NONE
NONE
NONE
NONE
1.00000
l.OOCOO
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
2017.20000
2017.20000
2017.20000
2017.20000
2017.20000
2017.20000
2017. 20000
6060.00000
1.00000
1.00000
1.00000
to
\o
Ul
-------
S Case 3: Spec. = 20 Ib SO_/MMBtu
en *
-------
MPSX-»TF13 EXECUTOR. MPSX RELEASE I MOO LEVEL 3
PAGE
18 - 74/183
SFCT ION
i
7
?
5
IA 6
7
1 - K'IWi
.. .pnw- -
rinsTTOTL
C" STPI T
rnSTASH
nsTse'i
TOSTSC2
CDSTWSH
ro«;TPFF
9 rnsTSTO
10 CnSTRRN
11 A" A
12 A^f-
11 AMC
14 AMH
15
16
1 7
1H
19
70
21
27
jl
AMF
AMF
AMR
AMH
DOC
000
nnc
10 74 DOF
J° 75 DIG
26 nn H
?7 001
78 DOJ
70 nn if
30
31
32
31
14
36
17
1R
30
40
42
43
45
48
49
DOL
DOM
DP 0
DO"
nno
no"
FPA
CP F
cr} p
FDG
F1H
EOJ
FOI
=01
AT
BS
EO
EO
FO
FO
EO
FO
EO
eo
EO
at
BS
BS
UL
UL
UL
as
as
FO
C0
EC
EO
FO
EO
FO
C0
EC
FO
cO
FO
FP
FO
eo
FO
CQ
EO
BS
BS
BS
BS
BS
BS
BS
BS
AfTIVTTV
326595.26326
7000. OOOOO
8000.00000
18684. OOOOO
12994.00000
17776.00000
20023.00000
24504. OOOOO
59525.00000
64R62. OOOOO
6491 7i OOOOO
43?! 9. OOOOO
67512.00000
i"*4fii onnnn
87017.00000
31570.00000
1 1 56R7- OOOOO
25608.00000
51307.00000
114RR. OOOOO
18259.00000
253180. >5174
I 76Q77. 27061
208375.08927
103876.35876
1 77 t ?*. l 711 ft
308806.88485
762474.61583
7^3156, 26604
585645.79019
367038.42430
45141 R.491S1*
1179137.41005
427794.20154
«l ATK AfTlVTTV
326595.26326-
"
1H741- 67040
50000.00000
38857.76709
ROOO. noooo
.
120499.54826
83807. 77919
146144.91073
296583.64124
167956. H76H4
881693.11514
534765.33416
535383.71195
278734.20981
983201.57561
715R01-«5ftfl47
561202. 5S994
203605.79845
-.1 ruFB 1 TMT.T.
NONE
NONF
NONE
NONE
NONF
NONE
NONE
NONF
NONE
18684.00000
12994.00000
17726.00000
20023.00000
24504.00000
59525.00000
64862.00000
64937.00000
43219.00000
67512.00000
H46I -OOOOO
87017.00000
31570.00000
I i«i6R?.oor»no
2560R. OOOOO
51307.00000
18259.00000
NONE
NONF
NONE
NONE
NONF
NONE
NONE
NONF
NONE
NONF
NDNF
NONF
NONE
.-IIPPFR 1 IMTT. n
NONE
snnoo.nnoon
50000.00000
50000.00000
7OOO. OOOOO
8000.00000
8000.00000
18684.00000
12994.00000
17726.00000
20023.00000
24504.00000
59525.00000
64862.00000
64917.00000
43219.00000
67512.00000
^3461 -OOOOO
87017.00000
31570.00000
1 15682.00000
25608.00000
51307.00000
18259.00000
373680.00000
7S9S80. OOOOO
354520.00000
400460.00000
4900RO-00000
119Q499.99999
1297239.99999
1298739-99999
864380.00000
1350239.99999
AAo?7n-nnnoo
1740340.00000
631400.00000
IIIAI ar.TiwtTY
1.00000
1.00000
1.00000
1.00000
1.00000
.41412-
1.00000
1.00000
1.00000
7-1019R
1.68674
.54325
134358-
.34358-
.4U157-
,5301-J-
.51004-
.49498-
.47599-
.47S99-
.39444-
.4a745-
.39J07-
.46043-
.19x01-
.32676-
.44890-
.46704-
.36581-
"
'
-------
MPSX-PTF13 EXECUTOR. MPSX RELEASE 1 MOO LEVEL 3
PAGE
19 - 74/183
50 F[)N
5t «?nn
52 EOP
53 FOO
54 FH"
55 SIZXOF
16 SI7XDG
57 SIZXDI
A 58 SIZXOJ
59 STZXDL
AO SIZXOM
61 SIZXDP
67 SIZXDO
<>3 E01PF
A 64 FOIPG
A 65 FOini
66 FO 1 P.)
67 F010L
6B E010M
A9 roipp
70 FOinO
71 CQ2DF
7? E07PG
Ni 73 F070I
**> 74 F.02DJ
00 75 FO?PL'
7ft FO7DM
77 FO?DP
78 P0200
4 79 EQ3DF
80 P03P.G
Rl E03DI
<\2 F030J
83 F030L
H7 F050F
8P F05HG
99 F050I
90 F05HJ
92 =050M
«»3 FO5OP
94 FQ500
A 95 FOSDF
* 96 FQ6RG
A 97 rOini
03 FQ&nj
99 E06DL
100 506DM
BS
BS
BS
BS
BS
EO
EO
EO
EO
EO
EO
EO
EO
RS
u:
UL
BS
UL
BS
UL
RS
BS_
BS
RS
BS
UL
BS
UL
UL
RS
BS
UL
UU
BS
UL
UL
BS
BS
RS
BS
BS
BS
BS
BS
EO
EO
EO
EO
EO
FO
198198.80960 2115441.19039
301030.64910 21 1 129.35089
87904.65521 938235.34478
370152.02589 259607.97411
214640.69346 150539.31654
*
* *
* *
« -
1*. 00000
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NCNF
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
2313639.99999
512160.00000
1026140.00000
629759.99999
365180.00000
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
.
.25720
.25720
.25720
^25720
.24214
.25720
.24214
3030.00000
4222.36364
2384.72727
2384172727
5581.00000
3030.00000
2186.00000
4222.36364
5581.00000-
3030.00000-
2384.72727-
-------
MPSX-PTF13 EXECUTOR. MPSX RELEASE 1 MOO LEVEL 3'
NIJMBFP -..Rnw.. AT -.-AfTtVlTV... SLACK ACTIVITY . .1 OUP R Lf MIT .
107
my
A
a
A
to
VO
A
A
A
A
A
A
A
103
104
I 05
106
107
1 Ofl
100
110
111
112
1 13
11 4
115
116
117
118
119
1 2C
121
12?
124
125
1 ?&
127
121
I 29
130
131
1 33
134
1 35
136
1 37
i 3fl
139
140
141
F06DP
POftOQ
HDF
mr,
HO I
HOJ
MOP
HOC
ir>p
JOG
JOT
JDL
JOM
.100
ST7YPN
$f 7 YHP
SI 7YMA
SIZYMB
iI7YMr
EO
FO
EO
FO
FO
EO
EO
EO
FO
FO
EO
EO
FO
EO
EO
FO
EO
FO
FO
EO
PO -
ST 7YMD EO .
SrZYPA F.O .
^1 7 YPB FO -
PAGE 20 - 74/183
..IIPPFR LIMIT. .DUAL ACTIVITY
2186.00000-
A&07. 04091-
.25720
.2*720
.25720
.25720
.00061
.24214
.0431.4-
.03900-
.03727-
! .03509-
.00068-
.04104-
.78682-
.76687-
.7b682-
.78t,82-
.78682-
.7668*:-
EOOJPN F.O «
E003DP F.O .
F003MB
F003PA
C003PB
TMA
FMB
nv f}
EO
EO
FO
EO
EO
FO
EO
FO
FO
FO
FO
T .78687-
.76682-
.78682-
.786B2-
.78682-
.7868?-
14?
2.66849-
-------
MPSX RELEASE 1 HOD LEVEL 3
PAGE
21 - 7W183
NUVBFR
145
153
159
191
199
209
225
233
25?
755
768
271
?79
797
305
379
335
340
343
0 1354
156?
2394
2395
239f.
?399
4897
.COLUMN.
WHCOA
WMCHB
W.AOC
WMAHG
W1ADH
WMCDI
WMTDK
WMTDL
WMCOM
WMFON
WY&DD
W1FOP
WMADO
WMAOR
WSMCDO
WSMCDI
U'SMfDM
KSMFDP
w SWA no
XMODPOD
XMDDPOF
XMDOPOJ
XVFDPOJ
XMAOOOJ
XSM4DODF
XSMFDPDJ
4895 XSMAOODJ
5917 YMDPBOD
6181 YvfMCDK
6799
6890
6«01
6802
6803
f.»04
6806
6filO
6R11
6817
6820
6873
6828
6829
6830
6832
SSIDF
ssmc
ssini
SS10J
SS1PL
SS i no
ss?nj
SS20L
S30G
S301
SIOJ
S30L
SI OK
S30H
AT
BS
BS
SS
BS
BS
BS
BS
BS
RS
BS
BS
BS
BS
RS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
85
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
RS
BS
BS
...ACTIVITY InlPUT COST.. ..LOhEft LIMIT. .
917.32129
637.96151
882.94529
3730.82464
3234.56045
2121.90691
1642.82207
'4272.24077
1549.98036
.5505.52249
1275.55360 . .
2441.79598
1568.44079
909.49442
.
837.71257
1025.18648
2490.37810 . .
2646.72285
52.68153
156.56041
! *. I
...
.
..UPPER LIMIT. .REDUCED COST.
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NOME
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
'
*
-------
MPSX-OTP13 FXECUTOR. MPSX PELEASE 1 MOO LEVEL 3
PAGE
22 - 74/183
COST.
6833 SinP
68T6 MDO
6837 S200
ftl^R S3DO
6819 CCIDN
6840 CCIDP
6841 CC1KA
68«? CC1M8
6843 CC1MC
6844 CCll1"!
6«45 CCIPA
6847 flHN
6849 C1HP
68 "51 CIMA
6852 C2MA
6 85 3 flMB
6856 C2*«C
6857 riMD
6861 CIPB
6881 TPIT
W 6881 TASH
P 6884 TSCl
6888 TSTT
6889 TBPN
6890 TN120F
6891 IN120C
6892 IN12DI
6897 IN 1200
689P IM230F
6899 IN250R
6900 IN23HT
6901 IN230J
AQf)9 1 N7 in 1
6903 IN230M
6904 TN230P
690ft IM120N
6907 [Ml?DP
ftQOO TM17MR
6910 IM12MC
6911 IM12^n
6912 IW12PA
6913 I^1?P8
BS
BS
BS
BS
BS
as
BS
BS
BS
BS
BS
BS
RS .
BS
BS
BS 220503.82821 1.00000
US 99144.19787 1. OOOOO
BS 4784.46465 1.00000
RS . 1.00000
RS . 1.00000
BS 2162.77258 1. OOOOO
BS . 1.00000
IV
IV
IV
TV
IV
IV
IV.
IV
IV
T V
IV
IV
T V -
IV
IV
IV
IV
TV
I V .
IV
NONE
NDNF
NONE
NONE
NONF
NONE
NONE
Nf1NF
NOME
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NflNF
NONE
NONE
NOMP
NONE
NONE
NPINF
NONE
NONE
NHNF
NONE
NONE
1.00000
1.00000
1.00000
1.00000
1.00000
1.00000
l.OOCOO
1.00000
1.00000
i .noonn
1.00000
1.00000
T .OOOOO
1.00000
I. OOOOO
i .nnnnn
1.00000
1.00000
1.00000
1.00000
-
.
-------
U)
Case 3: Spec. = 5 Ib SO./MMBtu
-------
c.
MPSX-PTF13 EXECUTOR. PPSX RELEASE 1 PCD LEVEL 3
i - nnws
PAGE
19 - 74/179
NUMBER
I
2
4
5
6
7
B
10
1 1
12
13
1 >
16
17
1R
1"
C» ?1
© 22
?4
2ft
77
31
3?
35
36
37
38
40
41
4?
43
44
45
46
47
*9
.. .RDW..
CTSTPIT
'CQSTASH
coSTsri
CUSTSC2
COSTWSH
COSTPEF
COSTS TO
CnSTBPN
A«.A
AMP
AT.
AMD
AMF
ANH
no A
i:nc
rpr
OOF
noc
nnl
rn.i
OOK
nrL
r>n,v
000
COP
mo
HOB
FDA
EOT
pnn
EOE
FOF
rnc
FOh
FO I
FO.I
FOK
F01.
AT
as
ED
FO
EO
F.O
EO
FO
FO
EO
BS
flS
BS
UL
Ul
UL
rtS
FQ
EC
FC
EO
EO
EC
EO
FO
EO
EO
FO
FO
EO
EO
EO
EC
EO
Ul
Ul
UL
UL
Ul
UL
UL
UL
UL
UL
UL
UL
'JL
...ACTIVITY... SLACK ACTIVITY ..LCWER UtMT.
361681. !>502C 331681
*
5404.12479 44595
72CC.OOOOC 4280C
1886.64147 48113
7000.00UUO
acoo'.ooooo
dOoC.OGOCO
1E684.000GO
12994. OCOCC
177?t.OOOCC
20023. ooocn
245C4.CCCCO
59525. OOCOO
64862.00000
64937. CCCCO
43219. OCCCC
67512.00000
33461.00000
6701 7.00000
31b7C.COOOO
1 15682.00000
?5t08.00CCO
51307. CCCCC
314P8. 00000
18259. OOCCC
93420.000^0
64970. CCOCO
86630. OCCCO
IOC115.COCCC
12252C.OOCCO
297625. OOOCO
324310. COCOC
324685.00000
2UCS5. OCCOO
33756C. 00000
1673C5.COOCO
15785C.COOCO
55020- NONE
;
.
87521 NGNE
00000 TTONE
35853 NCNE
NONE
NONE
NONE
NONE
18684.00000
12994.00000
17726. OOOCO
2C023. OOOCO
24504.00000
6S525.00000
64862.00000
64937. OOOCO
43219. OOOCO
67512. OOOCO
33461.00000
87017.00000
3157C. 00000
115682.00000
i5603. OOOCO
51307. OOOCO
31488.00000
18259.00000
NONE
NONE
fitffcE ^
NCNE
NCNE
NONE
NONE
NONE
NONE
NGNE
NONE
NONE
NQNB
..UPPER LIMIT.
NONE
\
sooooloooco
50000.00600
50000.00000
7000.00000
8000.00000
8000.00000
18684. OOCOO
12994.00000
17726. OOOOC
20023.00000
24504. OCCOO
59525. OOCOO
64862.00000
64937. OOCOO
4321 9.00CCO
67512. COCOO
33461. OOCOO
87017. OCCOO
31570. CCCOO
115682. OCOOO
256C8. 00000
51307.00000
31488. OCUOC
18259. OCOOO
93420.00000
64970. OCOOO
f!8630. OCOOO
1GU1 15. COCOO
122520. CCCOO
297625. OCCOO
324310. OOCOO
324685. OOCOO
1 216C95. OCCOO
337560. COCOO
435O85.0CCCO
l»7B90tOOOOO
.DUAL ACTIVITY
1.00000
l.OOOuO
1.00000
1.00000
l.OOOOu
.09273
1.00000
1.00000
1.00000
1.00000
2.31^60
1.6B7J2
.61434
.01962
.64il6-
.64516-
.53426-
.49744-
.59202-
.6/006-
.52376-
.63801-
.39541-
.45228-
.46107-
.02226
.02226
.00028
.00071
.00052
.00039
.00987
.00987
.00032
9»»tf* ,,-, ,-r- ,T -- - - -
.OliSb
-------
MPSX-OTFI3 EXFCUTCR
M)Mt»co ...POW.. AT
50
51
5?
55
56
59
61
6?
63
65
A 66
67
6rf
69
ro
71
7?
0 74
* 7-r
76
77
78
/9
!U
81
84
*>
flf.
B7
flP
-
2384.72727-
2384.72727-
3C3U.OOOOU-
-------
C- FPSX-PTF13 EXCCUTOR. PPSX RELEASE 1 MOD LF.VFL 3 PAGE
AT ...ACTIVITY... SLACK ACTIVITY ..LCHER LIMIT. ..UPPER LIMIT. «DUAL ACTIVITY
21 - 74/179
101
10?
103
104
105
ICfc
107
ion
109>
110
111 '
112
113
115
11 7
118
119
12C
U> 121
° 122
01 123
124
125
126
A 127
A 12*
A !?«,
MJ
A 111
A 1^7
A 133
A 134
1 35
1 36
1 17
138
141
147
E06RP
FOfcCQ
HDF
hDG
HOI
HOJ
HDL
HOP
HDP
.IOC
JTT
JD.I
.10 L
JOP
.100
SI ZYDN
SI ZYOP
S I 7 YV i
SI7YMB
SI ^YP A
SI 1 YPh
c*3 0 30\
CQ ^ ^f) F
FOC3MA
F003VK
F.OO^.C
F3CJPA
PQ03PB
Fn,\
=0?
FMB
r ic
FMO
TPA
FPR
EC
EO
EO
EO
FO
EO "
% '
E(J '
FO
EC
FO
EO
FO
FO
EO
FO
EO
FO
EO
EC
EO
FO
FO
EO
CO
= 0
EO
EO
CC
EO
EO
1=0
EO
FO
EO
EO
EO
EO
. 12518.40000-
. . 2186.00000-
-. « .00001
'. I ! 125720.
' . . - ' . .OO001
.24214
.25720
. ' IfdJLT
.OJOll-
.00058
'. '. '. .00292
.00048
. . . .01290-
.OUbO-
.03020-
I '. . 4.05059-
1.157JV-
- - - . . 1.9OUUO
.172J9
1.9000O
l.VUOOO
. . 1.9OOOO
1.90000
.
; . ' . 12438.79534-
" I . 4.0505S-
~ . . 1.15739-
1.90JOO
.17239
... 1.90000
1.90000
1.90000
. . . i.vuuoo
-------
EXECUTOR. HPSX RELEASE 1 HOC LEVEL' 3
SECT TON 2 - CUlur'NS
PAGE
22 - 74/179
NtJMBF.k
Us
153
159
? 11
2-5 /?
2S3
?<.£>
;;?
329
315
1-+1
OJ 933
w 2"
11 '.6
149
114
1S7
So?
77'
m
?1R9
?3
-------
MPSX-OTP13 EXPCUTOP. HPSX RELEASE 1 KQO LEVEL 3 PAG6
'.rrnuMN. AT ...ACTIVITY INPUT COST.. ..LOWER LIMIT. ..UPPER unit. ,REDUCED COST.
23 - 74/179
1
ft?l *i Y'l PVBCL
£335 YHBfPCf
fihoo ssinr.
6P03 SSIDI
6634 SS1TM
6?C5 SS10P
fclMl'5 SS2LI
cR16 SlCC
ft8?V CCIHN
f-p'»o ccinp
hfl«i cr ^A
*>P42 CCIVB
6 a 43 CCl.'-'C
^?45 CC1FA
A.T.f- CCIP6
6"s.l C1MA
tftSS C1MC
6P57 CIMP
6^S9 CIP4
iS P" I TP I T
6." .13 TASH
6?h4 TSCl
ftP'ift ThSH
fci- )7 Tr^FF
6jPP TSTT
hi. 'j i IN i ?n j
RS 4374.13077
" riS
'. BS
BS
BS ' '
BS
RS
BS
.RS
BS
BS
BS
BS
BS
BS
BS
rtS
BS
BS .
BS
BS
3S
BS
bS
BS
BS
OS
BS 72CO.OOOCO
BS
BS
3S
BS
BS
OS
BS l.OOOOC
BS
BS
BS
BS
BS 211C67. 28916 1
US 14420-;. 4S686 1
BS 3470.62239 1
RS . 1
BS 136PO. 00000 1
BS 446.400CO ' 1
BS 6£C7. 74179 1
BS . 1
IV
00000
00000
00000
OCOOO
00000
uouco
ocooo
oooco
NONE
NONE
NCNE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NCNE
NONE
NONE
NCNF
NCNE
NONE
NCNE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NOMI:
NCNE
NCNE
NONE
NONE
NPNE
NONE
NONE
NONE
NCNE
NCNE
NCNE
NONE
1.00000
.
-------
MPSX-PTF13 F?ECUTOR. KPSX PELFASE I MOD LEVEL 3
_JSA'^PFg_. .CPI UKN. AT ...ACTIVITY INPUT CCST.. ..ICWEP LIMIT. ..UPPER LIMIT.
PA (it
.REDUCED COST.
24 - 74/179
6H9
-------
o
vo
Case 3: Spec. = 3.1 Ib SO2/MMBtu
-------
MPSX-PTF13 EXECUTOR,
SFfTlOM 1 - hOWS
?PSX RELEASE 1 MOC LEVEL 3
PAGE
18 - 74/179
MJMBFR
1
2
3
4
5
ft
7
B
9
10
11
12
11
14
15
16
17
i a
19
;o
w?i
M?2
0;3
?4
?5
76
78
2<5
30
31
32
3?
34
JS
36
37
13
*9
40
41
42
41
'4
i5
46
<»7
AH
<.<>
.. .RHVt. .
CTSTTOTL
Cr»STPIT
COSTFRT
££STASI-
COSTSCl
CHSTSC?
COSThSH
r.nsTncF
CDSTSTD
COSTRK.M
AM A
AM«
AMC
AMD
flvp
AMF
A«f,
AMH
CDA
m?
Or>C
ODD
PDF
D'lF
DDT,
DDh
no i
Df!J
rriK
DO I
OT"
no\
one
OOP
ODC
onp
EOA
EPP
enc
EPH
EOF
fcDF
FOC
POH
FO I
f^J
FDK
FriL
F'lM
AT
BS
EO
to
FO
EO
EO
EO
EO
EO
FO
BS
BS
AS
UL
UL
UL
UL
Ul
EC
EC
FO
EO
FO
EO
EO
EO
~~EU
EC
FC
EO
EO
FO
FO
EO
EO
EO
Ul
UL
UL
UL
UL
UL
UL
UL
Ul.
UL
UL
UL
UL
...ACTIVITY... SLACK ACTIVITY ..LCWEP LIMIT.
414577*07576 414977
'
A
338.13609 49661
14398.39058 35601
E57.7U819 49142
7CCC. CCOCO
ecoo.ccooo
8COC.OC001
18684. OOCCO
12QV4. 00000
17726. GOOCC
20C23.COCCO
24bfi4. CCCCC
595^b.OUOOO
64862. OOOCO
64937.00000
43219. COOCfi "
67512. COOCO
33461. COCCO
P7C17.CCCC.O
31570. COOCO
1156R2.COCCC
25608. OCCCO
51307. OOOCO
31488. OCOCO
1S259.0CCCC
57920.38672
402C1. 39063
54950.58^84
62C71. 28516
75962. 375CO
184527.43750
201C72. 12500
2C1304.625CO
133978. 875CO
209267. 125CO
1037?9. C6250
2<«<752. 62r.CO
<)7t66.39<*-
.95392-
.75726-
.80670-
.7U566-
.7698B-
.85991-
.85991-
.95^30-
.76199-
.77288-
.977U9-
.93142-
.62^56-
.B712V-
.722b3-
,7&279-
.9wiys-
.08037
.08037
.031 76
.03219
.03
.03180
.02042
.idOli
.047V1
-------
MPSX-PTF13 E>ECUTCR. MPSX RELEASE 1 HCO LFVEL 3 PACE
MJKBFP ...ROW.. AT ...ACTIVITY... SLACK ACTIVITY v.LOWER LIMIT. ..UPPER LIMIT. .DUAL ACTIVITY
- 74/179
50
5?
53
55
56
57
58
59
61
63
64
65
fc/S
f P
69
70
71
72
CJ 71
M "
M 75
7t,
77
78
79
80
HI
81
H4
85
06
P7
HH
90
«
cr,
97
cp
A 99
IOC
f-OP
CDB
too
FOR
SIZ>OF
SIZXPG
iizxni
M/XOJ
SI7XTI
M ZXPX
SI7XGP
si7xnc
FO ITF
rC}£'
f-oinp
F01CC
r??SJ
MJ?PF
FOin
^03rL
e"pp
Fas"?
C Q ^ pp
c n *j n ^3
EOftDF
F Of- 0.1
'Uf.DL
pj(.nw
UL 35P614.121CO
UL 7S384.7500C
UL 159C51.625CO
111 97612.75000
UL it60?.B6672
FO
EO
EO
EO '
FO
EO
EO
US
BS
UL
RS
III
UL
UL
PS
UL
PS
as
ns
BS
UL
UL
UL
Ul
UL .
UL
UL
Lit
UL
fiS
BS
as
ns
BS
?s
EO
F.O
FO
EO
?0
NCKE 358614
NCK'E 79384
NCNE 159051
NCNE 97612
NCNE 56602
* *
I
< ! NONE
NCKE
NCNE
NCNE
NCKE
NONE
NONE
NCNE
NCNE
! NCNE
NCNE
NCNE
NCNE
NCNE
NCNE
NCNE
NCNE
NCNE
NOKE
NCNF.
NCNE
NONE
l.OCLOO NONE 1
1.00000 NCNE 1
l.OOCOO NCKE 1
l.OOUCO NONE 1
1.00000 NCNE 1
l.CCCCC NCNE 1
l.OCCGC NCNE 1
l.OCOOC NONE 1
.
.12500
.75000
.62500
.75000-
.88672
;'
1
-
;
.00000
.00000
.00000
.oocoo
.occoo
.oocoo
.oocoo
.00000
.
.
.00557
.07306
.03073
.03172
.07220
.25720
.24214
.2o226
.29429
.25720
.24214
.24214
844.00000
844.00000
4222.36364
4222. J6364
2384.72727
*
2384.72727
2384.72727
2186.00000
2920.50064
3C30.0JOOO
5875.62004
3030.00000
4222.36364
4222.36364
*
j
2186.00000-
2384.7*727-
2119. 22721-
3030.00000-
3C30. 00000-
-------
MFSX-PTF13 FXECUTOR. NPSX RELEASE 1 MOO LEVEL 3 PAGE
MJMREP ...30V... AT ...ACTIVITY... SLACK ACTIVITY ..LCWFP LIMIT. ..UPPER LIMIT. .DUAL ACTIVITY
20 - 74/179
101
10?
103
104
105
10*
107
lOb
109
1 10
111
112
11 3
1 Ic
117
119
*° 123
124
12r>
176
A 127
A 128
129
A 1 10
A 111
A 132
A 1 J3
A 1 14
1 Ib
137
13R
139
14C
1 4y>
F060?
F.060Q
Hi)F
HDG
HP I
HOJ
HF-P
HDD
jni
Jf\l
JHL
.irjv
.irip
jno
5T7Yr.N
SI 7YPP
SI ZYMA
SI ZV9
SI 7VMC
SI7YMD
F.JC^N
E"Sr
FOCiPA
FDN
P'np
FMH
FMC
ppa
FPfl
EO
EO
EO
FO
EO
FO .
FO
FO
EO
FO
EO
FO
FO
EC
FO
EO
FO
EO .
EO
EO
EO
EO
rO
FO .
FO
EO
EO
EO
FO
EO
EO
FC
FO
EO
FO
EO
EU
FO
EO
EO
FO
EO
6607.09091-
66C7. 09091-
.26226
'. . . .25720
. . . .242 U
.24214
.03150
.01752
.03150
.OOJ40-
.03150
.03150
.00136-
.00192
1.90000
1.90000
2.31561
1.90000
1.21624
1.90000
1.90000
1.90000
99745.32085
'.'.'.'.
1.90000
1.90000
2.31561
1.90000
1.21624
1.90000
1.90000
1 .9DOOD
-------
MPSX-PTF13 EXECUTOR
SECTION 2 - COLLINS
KPSX PFLFASE 1 MCC LFVEL 3
CASE
- 74/179
199
775
711
7.5?
7-J4
266
768
10T
315
5C9
717
941
1146
1149
M I5'i7
1770
1773
1078
1931
7304
2'iHS
7P13
3071
3437
38S8
1S60
4069
4R95
5775
5615
6015
621 5
(* 15
.COLUMN.
WMAfiH
W.f.DK
UMCD'i
WMH13N
xsi^&ni
XSXACP
EEi
X"'COPCC
X-'GTPOP
sS
xMprpnc
XMCOPOI
Ess
XMRCPIJC
XMGHPrO
xsr-rnpRF
y ^ ^' * n c ^ i
VMRf'pr^A
YMRMBCB
Y'lftf'ARH
viibf'HP^
v"'BvJSn
AT
BS
BS
BS
3S
BS
BS
BS
BS
OS
BS
BS
BS
BS
HS
BS
BS
BS
BS
BS
BS
ns
*BS
BS
BS
BS
3S
BS
BS
bS
BS
BS
RS
BS
as
BS
BS
BS
BS
BS
tiS
BS
BS
BS
BS
BS
BS
BS
338.13609
197.44S15
66b. 33904
4860.57531
' 6b6. 69138
1467.27484
*
125.32999
fl7. 16216
409.64799
146.18659
391.04675
566.28752
476.56019
1375.62253
1162.51616
284.03898
552.67859
616.78714
1685.24184
28S. 90768
1560.20249
1318.5C135
1405.92C69
583. bllSS
211.76827
171.77579
667.9U951
266.22916
433.14593
12
-------
c.
MPSX-PTFU FXECUTOR. KPSX. PEIEASE i VCD LEVEL 3
.COHIMN. AT ...ACTIVITY INPUT COST.. ...LCWFR LIMIT.
PAGE
22 - 74/179
.UPPER LIMIT. .REDUCED COST.
6455 YMBMBQR
6800 ssinr,
6801 SSIRt
66C? ssinj
6803 SSIHL
*fl04 ssihn
6805 SS1PP
6006 SS1PO
6fl07 SS2PF
66C9 SS2CI
6flii ss?n
6812 SS2CH
6815 S1DF1
ofil7 S30F
6818 SlOG
6870 S3n<:
6821 Sim
6P23 S3DI
'824 SIOJ
6825 S70J
6826 S1DJ
6829 S101
6830 S1DM
li) 6P31 S20M
t-1 6832 S30C
* 6333 SIDP
t8J5 S3CP
6836 Sl^O
6637 S2HO
6838 S3HO
68 49 r.cinN
6^40 CC1HP
6842 CC1PB
6043 CC1MC
6844 CCl^O
6845 CCIP*
6846 CC1PB
6R47 C1DN
6849 C10P
605? C?MA
6853 n*!fl
fa54 C2HB
6857 CI"D
6859 C1"A
fcrt6l C1PB
ftP.Sl TSJT
6o3? TF?T
68S4 TSC1
BS S06.79766
BS
BS
BS
BS
as
BS
BS
as
BS
as .
as
as
as
BS
BS
BS
BS
BS
BS
BS
BS .
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS 14398.39058
BS
BS
BS
BS
BS
BS
BS
BS .969C8
BS .03092
BS
BS
PS
BS 717964.46783 1
BS 15666C. 25761 1
BS 2Glfl. 55324 1
BS 1
00000
00000
00000
ocooo
NONE
NONE
NONE
NONE
NONE
NtNE
NONE
NONE
' r NONE
NONE
NOME
NCJNE.
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
NONE
-------
MPSX-PTF13 EXECUTCft. I*PSX RELEASE I MOD LEVEL 3 PAGE 23 - 74/179
NUMBER .COLUMN. AT ,..ACTIVITY INPUT CCST.. ..LCWEH LIMIT. ..UPPER LIMIT. .PEDUCEO COST.
t-Ce.5
68 86
6Bb7
68flR
6RR9
6B94
6896
6697
f.RSR
6899
6901
6903
6904
6905
6906
6907
A 6909
6910
6911
6912
6913
TSC?
THSH
TBEF
TSTf
TBPN
TN12ni.
IN17PP
IN120C'
IN23CF
IN?3DG
TN22PJ
IN230y
IN22PP
IN230C
IM12TN
IM12DP
IMI?MR
IM12MC
1^1/MO
IM12PA
1M12PB
BS
PS J7356
BS 892
AS SC64
BS
IV
IV
IV
IV
l,v
IV
IV
IV
IV
IV
IV
IV 1
IV
IV
IV
IV
1
94210 1
7C022 1
15472 1
1
00000
oococ
GCOOO
00000
ucocc
00000
NONE
NONE
NONE
NONE
NCNE
1.00000
1. GCOOO
1.00000
1.00000
l.OOCOO
1. '0(3000
uoocoo
1.00000
1.00000
l.COCOO
1.00000
l.OOCOO
1.00000
l.OOCOO
l.OCOOO
l.OOCOO
Ul
-------
U)
M
O\
Case 3: Spec. = 1.2 Ib SO2/MMBtu
-------
MPSX-PTF13 EXECUTOR. MPSX RELEASE 1 I*CO LEVEL 3
SECTION 1 - ROWS
PAGE
19 - 74/179
MJMBER
1
?
3
*
5
6
7
8
9
10
11
12
13
14
15
If-
17
18
19
20
U» 21
H- 2?
^ 23
24
?S
26
?7
?R
29
10
11
32
33
14
35
36
37
38
39
40
41
42
43
44
45
46
4 r
48
AS
.. .«CI». .
CnSTTCTL
COSTPIT
COSTFPT
CO STASH
COSTSC1
CCSTSC7
CQSTkSH
r.nsTocn
f.nSTSTO
CPSTBRN
AK A
AMD
AMC
AMD
ufcr
AMF
A"G
AHH
on A
oon
oor
con
Cf>c
CDF
nor
DOH
on i
DOJ
cnK
DHL
one
DON
noo
nnn
ODO
OOP
EDA
EDP
FOC
EDO
EDE
PDF
FDG
CTH
EI; I
FOJ
FOK
fDI.
ROV
AT
BS
EO
EO
EC
EO
to
FO
EO
EO
FO
BS
BS
BS
UL
UL
UL
UL
UL
EO
EO
EO
F.O
EO
FO
EO
EO
EO
FO
EO
EC
EO
FC
EO
EO
EO
EO
UL
UL
Ul
UL
UL
UL
UL
Ul
UL
UL
UL
UL
UL
...ACTIVITY... SLACK /.CMVITY ..LCWEP LIMIT
543834.11199 543834
6PP4. 98408 43115
7649.43175 4235C
5000C
7GOC. 00000
8CCO.CCOCO
8COO.OCOCO
18684. 00000
12S94.000CO
I 7126. COOCO
?OC23.0CUCC
24504. CGOCO
5S525.000CO
64E62. 00000
64537. OOOOC
4321 9.CCCCC
67512. OOOCO
33461. OOOCO
87C17.00CCO
3157C.OCOOC
115682. OCOCO
25608. OOCCO
51307. OOOCO
314R6. OOOCO
16259. OOOCC
22420. 79.2 <3T
1 "592.75688
21271.19531
24027.59375
?9404.7S297
7142<5. 93750
77834. 375CO
77S24.J75CO
51P62.7B906
31C14.375CO
40153. 19141
104420.37500
37EU3. 99219
11199- NONE
G1592 * NONE
56825 NGNE
00000 NONE
NCNE
NCNE
NONE
NCNE
NCNE
16684.00000
12994. OOOCO
17726. COOOO
2C023. OOOCO
24504.00000
5S525. 00000
64862.00000
64937.00000
43215. COOOO
67512.00000
33461.00000
87C17. 00000
3157C-. OOOCO
115682. COCOO
256C8. 00000
51307. COOOO
31488.00000
18259. 00000
NCNE
NCNP
NCNE
NCNE
NCNE
NCNE
NCNE
NCNE
NCNE
NCNE
NCNE
NCNE
NCNE
. ..UPPER LIMIT.
NONE
5000C.OOCOO
50000. OOCOO
50000.00000
7COO.OCCOC
8CCC.OCOOO
8COC.OCOOO
18684.00000
12994.00000
17726.00000
2CC23.0CCOC
24504. CCCCO
59525. OCCOO
64862. COCOO
64937.00000
43219.00000
67512. COOOO
33461. CCCOO
C7C17. OOCOO
31570. CCCOC
115682.00000
25608. 00000
51307. CCOOC
31486. CCCOO
18259. OCCOO
22420. 79297
15592.79688
" 21271.19531
24027.59375
29404.79297
71429.93750
77834.37500
77924. 375CO
51862.78906
81014.37500
4C153. 19141
104420. 37500
37883.99219
.DUAL ACTIVITY
1.00000
1.00000
1.00000
1.00000
i.ooooo
l.OOOOU
1.00000
1.00000
1.00000
1.00000
5.25304
3.5^01 0
8.8U596
13.37522
5.91767
1.34422-
1.34222-
1. 15012-
1.19736-
1.1772o-
1.0469J-
1.03975-
1.24321-
.97916-
1.01940-
1.18968-
.955UU-
1.04800-
1.07977-
1.25959-
.98802-
1.01*82-
1.293'3b-
.19795
.1V795
. 15603
.15420
.15588
.07874
.09181
.15024
.0877J
.07874
.16093
.10271
.03933
-------
MPSX-PTF13 FXFCUTOR. MPSX RELEASF 1 HOD LEVEL 3
...POta.. AT ...ACTIVITY... SLACK ACTIVITY ..LOWER LIPIT.
PAGE
..UPPER LIMIT. .DUAL ACTIVITY
20 - 74/179
50
51
5?
51
54
55
56
57
5H
59
60
61
k?
f-3
64
6<;
AA
67
68
6«J
7C
71
7?
LO "
H 7',
00 75
7«.
77
7S
79
riO
81
82
fl3
Vt
P«
86
87
18
89
03~'l-
.17051-
.429c9-
.22729-
.55186-
.57185-
.20592-
. 72656-
.59629-
.82949-
l.COCOO
1.00000
1.00000
1.00000
1.00000
1.00000
l.COOOO
l.COOOO
*
.57C31
.77271
.44814
.42815
.79408
.27344
.40371
.17051
.42969
.22729
.55186
.57185
.20592
.72656
.59629
.82949
NCNE
NCNE
NONE
NCNE
NGNE
NONE
NCNE
NCNE
NCNE
NOME
NCNE
NONE
NCNE
NCNE
NCNE
NCNE
NCNE
NCNE
NCNE
NCNE
NCNE
NONE
NCNE
NCN1:
NCNE
NCNE
NCNE
NONf
NCNE
NCNE
NCNE
NCNE
NCNE
NONS
NONE
NONE
NCNE
138816.37500
30729.59375
61568.38672
37785.59375
21910.79297
«
-
»
1.00000
1. OOCCO
l.COCOO
l.OCCOO
l.OOCOO
l.CCOOO
l.COCOO
l.OCCOO
.
.
.
.
.
.16967
.19064
.08358
.OdS79
.18978
.26998
.26998
.26998
.2699d
.26998
.2o99B
.26998
.26998
404Z.BUOOO
4042.80000
4042.80000
4042.30000
4042.80000
4042.80000
4C42.8UOOO
4C42. 80000
j
2017.20000-
2017.20000-
2017.20000-
2017.2000J-
2C17. 20000-
2017.20000-
-------
MPSX-PT=13 EXFCUTQP. MPSX RELEASE 1 HOC LEVEL 3 PAGE
NIIMBFR ...POW.. AT ...ACTIVITY... SLACK ACTIVITY ..LChEP LIMIT. ..UP"ER LIMIT. .DUAL ACTIVITY
21 - 74/179
U)
M
VO
A
A
A
A
A
A
101
102
103
104
105
106
107
108
109
110
111
112
1 13
114
115
116
117
1 13
119
120
121
123
124
125
\?.f>
129
129
130
131
13?
133
134
ns
136
137
138
1 39
140
141
14?
r-06RP
FW6TC
HUF
HOI
nn.|
HJL
HO*
HOP
HDO
JOF
JOG
JO I
JDJ
JOL
JDK
JOP
JOC
SIZYCN
SIZYCP
SI ZY^A
SI ZYMB
Sf 7YMC
SI 7YMC
SI 2YPA
si ZYPB
FQ030N
FOC3CP
= 00314*
FOC3MB
EOC3"C
EOC3PA
Fijo
FMB
FI«C
pot
FOR
EO
EO
eo
FO
FO
EO
EO
EO
EO
EC
EO
EO
EO
EC
EO
EO
EO
EO
FO
EO
EO
EO
EC
EO
EO
EO
EO
FO
EO
FO
EO
F.O
EO
EO
EO
EO
EC
F.O
FO
EO
FO
EO
2017.20000-
2017.20000-
.26996
.26998
.2699U
.26990
.26998
.26998
.03150
.OJ150
.03150
.03150
.03150
.03150
.03150
.03150
1.90000
1.90000
1.40767
1.36800
1.0U02
1.90000
1.90000
1.90000
3544.79846-
3830.40355-
1.90000
1.90000
1.40767
1.36800
1.01202
1.90000
1.90000
1.90000
-------
HPSX-PTF13 EXECUTOR. PPSX RELEASE 1 t>CC LEVEL 3
2 -
PACE
22 - 7W179
NUMBER .COLIJ"N.
253 WMfiTN
254 v-fHR".'
303 NS."ABT
370 V.SCBDI
377 hSKflOM
33a v.sT:np
509 XVGlKfifl
717 XMGnviDG
940 XMFrPCC
941 XMGDPOf.
1148 XMFTPOn
1149 XMGHPDC
1357 XMGPPDE
156? X^.OOFDF
1*71)0 X.-IFDPriH
loni XMCCPCH
7394 XMDCPDJ
W 7396 XMFC°nj
W 20HP XMFCIvDK
47*6 XSXDHPnF
4.JSO XSVOOPDJ
4891 XSi-'tDPOJ
5775 Y^BI^BDA
6015 Y^e'-'BflG
6C5'5 V'^MftDH
6CS5 Y'-IECFni
M35 YHPNiRC.I
6215 Y'-IBMROL
6? 55 YMBMRD"
6335 YMD"hCO
AT
RS
BS
BS
BS
BS
BS
BS
BS
3S
BS
BS
BS
3S
as
BS
BS
BS
BS
BS
BS
B~5
BS
BS
BS
BS
BS
BS
BS
as
BS
BS
BS
BS
BS
BS
BS
BS
BS
6^;l) YMHrfscp BS
6415 Y ' 1 '3 M i $ H 0 B S
6455 YMB-'RC0 BS
6579 YSMAi'lfiCC BS
f655 YSriFi'.BOL BS
6701 YSfC."CDH BS
6791 SSll'F
6FGO ssinr,
6807 SSI P.I
05
BS
RS
as
BS
...ACTIVITY IN
3130.20596
2177.58CC3
3197.78484
2130.75538
44S. 43175
1556.44386
1667.01427
634.06352
440.96665
479.64270
333.67151
541.79652
J76.9C992
663.04662
461.25956
263.34477
1 33 6. S 84 20
1457.CC568
85.02681
942.91240
905.41152
629.86472
669.03756
619.64065
2L27. 03333
1734.50514
1C23. 07568
243.61910
169.42770
38.92650
202.44867
25.93774
247.01273
1256.30805
18.94661
333.90062
672.65560 '
412.82050
23
-------
MPSX-OTF
NUMBPP
6804
AP05
6806
6807
6«0fl
6P.09
6810
6811
6812
6813
6P14
6S1 5
6fl6
6R17
6618
6820
6821
6P2?
6G23
AP24
6P25
6826
iU>6R27
6F3C
6P32
6P33
68J4
fif 3r>
6F36
6837
6fl3a
6P39
6H40
684?
6843
6F4*
6P45
6P46
6647
6G49
6P51
fcR53
6F57
6b59
6861
6H31
13 EXFCUTOR. PPSX PELEASE 1 MOC LEVEL 3 PAGE 23 - 74/179
.COLUMN. AT ...ACTIVITY INPUT CCST.. ..LCWER LIMIT. ..UPPER LIMIT. .REDUCfcD CUST.
SS1HM
SSIPP
SS1DQ
SS20F
SS20G
SS2HI
SS2HL
SS20M
SS2PP
S?DF
S30F
SI DG
S2nr,
S30G
S1PI
S3DI
S1CJ
S2nj
S30.I
sini
s?r.t
S3HL
SI Of
S 1 r P
S3CP
stoo
S2DC
S3!)C
CC 1DN
CC1DP
CC1MA
cr INB
CCl^C
cr i no
CC IPfl
CC1PO
C1RN
C1DP
Clh-a
C1PA
CIPK
TP IT
ns
BS
RS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
OS
BS
BS
BS
BS
BS
bS
BS
BS
BS
BS
BS
BS
BS
HS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
BS
US
BS
BS
BS
BS
BS
BS
31247. 14975
39844.96340
24453.54778
157604.90620
378772.09196
252304. 29477
12C520. 09208
145531.82110
184358. 08711
123519.28103
75805.93334
.42969
.57C31
.22729
.77271
.55106
.44814
.57185
.42815
.2C592
.794C8
.72656
.27344
.59629
.40371
.82949
. 17051
720C.OCOCO
1.00000
21 1340.09894
NONE
NCNE
NONE
NONE
NCNE
NONE
NONE
NONE
NONE .
NONE
NONE
NCNE
NCNE
NCNE
NONE
NONE
NONE
NCNE
NONE
NONE
NONE
NONP
NONE
NOlMb
NONE
NONE
NCNE .
NONE
NCNE
NONE . =
NONE
NONE
NONE
NONE
NCNE
NCNE
NONE
NONE
NONE
NCNE
NONE
NONE . ...
NONE
NONE
NONE
NONE
NCNE
NONf . ' =
NCNE
NCNE
1.00000 . NONE . '
-------
c.
MPSX-PTFI3
24 - 74/179
IVIIMbf-K
6831
f.885
f.P<%7
f 3R.1
'sag
6B9?
6895
6896
*8«J7
6906
6907
6909
«i9lO
6911
6913
U)
to
to
L i j L i ' " r
TF"T
TA5I-
TSC1
TSC2
Tf FF
IN1?OF
IN l?DI
IM170J
IN120L
!>J 1?DP
IM120C
M 12DP
IMIZHD
i. Al
RS
RS
BS
RS
PS
RS
BS
BS
IV
IV
IV
tv
IV
IV
IV
IV
IV
IV
IV
IV
IV
IV
IV
348S.395CO
45564.63959
1368C.CCOCO
446.40000
6967.55992
l.OOOCC
l.OOOCC
1.00000
1.00000
l.OOOCC
l.OOOCO
l.OOOOC
l.OOGCC
l.OOOCO
..INPUI LUil.. ..Ll'WtK I. If
l.OOCOO
l.OOOOC
i.uoooo
1.00000
l.OCOCO
l.OOCCO
l.OCOOC
1.00000
.
I j
-; j
HI. ..UI'KtH L ini <
NONE
KCNE
NONE
NONE
NONE
NONE"
NONE
NONE
1.00000
1.00000
l.CCCOO
"l.OOMO"
1.00000
1.00000
1.00000
1.00000
l.OOCOO
l.OCOOO
1.00000
1.00000
1.00000
1.00000
l.OOCOO
KfUUlCU IU3 1 .
\
2017.20000
2017.20000
2C17. 20000
2017.20000
2017.20000
2C17. 20000
2017. 20000
2017.20000
3830.40355
-------
TECHNICAL REPORT DATA
(Please read Instructions on the reverse before completing)
REPORT NO
EPA-650/2-74-127
3. RECIPIENT'S ACCESSION-NO.
4. TITLE AND SUBTITLE
Evaluation of Sulfur Dioxide Emission Control
Options for Iowa Power Boilers
5. REPORT DATE
December, 1974
6. PERFORMING ORGANIZATION CODE
7. AUTHOR(S)
D. 0. Moore, Jr., J. M. Peters, W. S. Alper,
E. Rosen, and J. R. Burke
8. PERFORMING ORGANIZATION REPORT NO
9 PERFORMING ORGANIZATION NAME AND ADDRESS
The M. W. Kellogg Company
1300 Three Greenway Plaza East
Houston, Texas 77046
10 PROGRAM ELEMENT NO.
1AB013; ROAP 21ADD-079
11. CONTRACT/GRANT NO.
68-02-1308, Task 3
12. SPONSORING AGENCY NAME AND ADDRESS
EPA, Office of Research and Development
NERC-RTP, Control Systems Laboratory
Research Triangle Park, N. C. 27711
13. TYPE OF REPORT AND PERIOD COVERED
Final; 7/73-11/74
14. SPONSORING AGENCY CODE
15. SUPPLEMENTARY NOTES
16. ABSTRACT
The report gives results of an evaluation of S02 emission control strategies
for major coal burning boilers in Iowa, considering options such as using low-
sulfur Eastern and Western coals, mechanical coal cleaning, and flue gas desul-
furization (FGD). Major utility boilers were surveyed, probable coal sources
were determined, and alternate transportation routes were defined. Coal cleaning
plant and FGD design studies were performed. Cost data were generated and a
linear computer program model was developed to determine minimum cost strategies
for meeting emission levels corresponding to no-control and control to 5.0, 3.1
and 1.2 Ib S02/MM Btu. For the cases studied, FGD was most cost effective only
for the most restrictive emission level (1.2 Ib/MM Btu) and when the supply of
low-sulfur coal was limited. Importing low-sulfur Eastern and Western coals or
combinations of mechanical coal cleaning and low-sulfur coal import gave the
lowest cost for all other cases. These conclusions are not generally applicable
to other states because of differences in the distances low-sulfur coal must be
transported, the washability characteristics of local coals, the size of the
power plants, the power plant network and other factors.
17.
KEY WORDS AND DOCUMENT ANALYSIS
DESCRIPTORS
b IDENTIFIERS/OPEN ENDED TERMS
c COSATI Field/Group
Air Pollution
Sulfur Dioxide
Boilers
Electric Power Plants
Utilities
Coal
Flue Gases
Desulfurization
Coal Preparation
Transportation
Cost Effectiveness
Air Pollution Control
Stationary Sources
Iowa
Low-Sulfur Coal
13B, 21B
07B, 07A, 07D
13A, 081
10A
15E
21D, 14A
8 DISTRIBUTION STATEMENT
Unlimited
19. SECURITY CLASS (ThisReport)
Unclassified
21 NO. OF PAGES
331
20 SECURITY CLASS (Thispage)
Unclassified
22 PRICE
EPA Form 2220-1 (9-73)
323
-------
INSTRUCTIONS
1. REPORT NUMBER
Insert the EPA report number as it appears on the cover of the publication.
2. LEAVE BLANK
3. RECIPIENTS ACCESSION NUMBER
Reserved for use by each report recipient.
4. TITLE AND SUBTITLE
Title should indicate clearly and briefly the subject coverage of the report, and be displayed prominently. Set subtitle, if used, in smaller
type or otherwise subordinate it to main title. When a report is prepared in more than one volume, repeat the primary title, add volume
number and include subtitle for the specific title.
5. REPORT DATE
Each report shall carry a date indicating at least month and year. Indicate the basis on which it was selected (e.g. date of issue date of
approve!, date of preparation, etc.).
6. PERFORMING ORGANIZATION CODE
Leave blank.
7. AUTHOR(S)
Give name(s) in conventional order (John R. Doe, J. Robert Doe, etc.). List author's affiliation if it differs from the performing orgam-
8. PERFORMING qRGANIZATION REPORT NUMBER
Insert if performing organization wishes to assign this number.
9. PERFORMING ORGANIZATION NAME AND ADDRESS
Give name, street, city, state, and ZIP code. List no more than two levels of an organizational hirearchy.
10. PROGRAM ELEMENT NUMBER
Use the program element number under which the report was prepared. Subordinate numbers may be included in parentheses.
11. CONTRACT/GRANT NUMBER
Insert contract or grant number under which report was prepared.
12. SPONSORING AGENCY NAME AND ADDRESS
Include ZIP code.
13. TYPE OF REPORT AND PERIOD COVERED
Indicate interim final, etc., and if applicable, dates covered.
14. SPONSORING AGENCY CODE
Leave blank.
IS. SUPPLEMENTARY NOTES
Enter information not included elsewhere but useful, such as: Prepared in cooperation with, Translation of, Presented at conference of.
To be published in. Supersedes, Supplements, etc.
16. ABSTRACT
Include a brief (200 words or less) factual summary of the most significant information contained in the report. If the report contains a
significant bibliography or literature survey, mention it here.
17. KEY WORDS AND DOCUMENT ANALYSIS
(a) DESCRIPTORS - Select from the Thesaurus of Engineering and Scientific Terms the proper authorized terms that identify the major
concept of the research and are sufficiently specific and precise to be used as index entries for cataloging.
(b) IDENTIFIERS AND OPEN-ENDED TERMS Use identifiers for project names, code names, equipment designators, etc. Use open-
ended terms written in descriptor form for those subjects for which no descriptor exists.
(c) COSAT1 FIELD GROUP - Field and group assignments are to be taken from the 1965 COSATI Subject Category List. Since the ma-
jority of documents are multidisciplinary in nature, the Primary Field/Group assignment(s) will be specific discipline, area of human
endeavor, or type of physical object. The appucation(s) will be cross-referenced with secondary Field/Group assignments that will follow
the primary postmg(s)
18. DISTRIBUTION STATEMENT
Denote reusability to the public or limitation for reasons other than security for example "Release Unlimited." Cite any availability to
the public, with address and price. /
19.&20. SECURITY CLASSIFICATION
DO NOT submit classified reports to the National Technical Information service.
21. NUMBER OF PAGES
Insert the total number of pages, including this one and unnumbered pages, but exclude distribution list, if any.
22. PRICE
Insert the price set by the National Technical Information Service or the Government Printing Office, if known.
EPA Form 2220-1 (9-73) (Reverse)
------- |