EPA-650/2-74-109
NOVEMBER 1974
Environmental Protection Technology Series
-------
EPA-650/2-74-109
CHEMICALLY ACTIVE
FLUID-BED PROCESS
FOR SULPHUR REMOVAL
DURING GASIFICATION
OF HEAVY FUEL OIL -
SECOND PHASE
by
J. W. T. Craig, G. L. Johnes, Z. Kowszun,
G. Moss, J. H. Taylor, and D. E. Tisdall
Esso Research Centre
Abingdon, Berkshire, England
Contract No. 68-02-0300
ROAP No. 21ADD-BE
Program Element No. 1AB013
EPA Project Officer: S.L. Rakes
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
November 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 the Agency,
nor does mention of trade names or commercial products constitute
endorsement or recommendation for use.
ii
-------
ABSTRACT
This report describes the second phase of studies on the CAFB
process for desulphurising gasification of heavy fuel oil in
a bed of hot lime.
The first test of the continuous pilot plant with U.S.
limestone BCR 1691 was hampered by local stone sintering and
severe production of a sticky dust during start up conditions.
Batch tests confirmed that BCR 1691 produced more dust than
either of the higher purity Denbighshire or U.S. BCR 1359
stones. With BCR 1691, dust production rate was tenfold
higher during kerosene combustion at 870 deg. C than during
gasification/regeneration cycles.
Modifications were made to the continuous pilot plant to
improve operability and three more runs were made using
BCR 1359, BCR 1691 and Denbighshire stone totalling 1167 hrs.
In the final run 211 hours of uninterrupted gasification
were achieved.
Improvements in gas analysis techniques allowed good material
balances on process streams, including sulphur. Maximum
sulphur removal efficiency under lined out conditions was
84%. This was limited by a maximum attainable bed depth of
61 cm (24 inches). Results indicate improved sulphur removal
efficiency with deeper beds.
An engineering scoping study estimates that total CAFB
development through a large demonstration test will take
about 6-7 years and require $3,320,000 in engineering effort.
This report was submitted as a requirement of Contract No.
68-O2-O3OO by Esso Research Centre, England under the
sponsorship of the Environmental Protection Agency.
- iii -
-------
CONTENTS
Page
ABSTRACT iii
LIST OF FIGURES vi
LIST OF TABLES viii
ACKNOWLEDGMENTS X
SECTIONS;
I CONCLUSIONS 1
II RECOMMENDATIONS 5
III INTRODUCTION 7
IV DESIGN AND CONSTRUCTION OF EQUIPMENT 15
Batch Units 15
Continuous Pilot Plant 18
Modifications to Pilot Plant - Run 4 19
- Run 5 2O
- Run 6 23
- Run 7 24
V PROGRAMME OF WORK 28
Task I 28
Task II 37
Task III 39
VI DISCUSSION OF RESULTS 4O
Task I 40
Task II 92
Task III 117
VII REFERENCES 12O
VIII INVENTIONS 121
IX GLOSSARY 122
- iv -
-------
CONTENTS (Continued)
APPENDICES 124
A - Run 4 Log, Inspection and Data 125
B - Run 5 Log, Inspection and Data 133
C - Run 6 Log, Inspection and Data 243
D - Run 7 Log, Inspection and Data 359
E - CAFB Pilot Plant Operating Procedure 474
F - CAFB Pilot Plant Alarm Systems 486
G - Cyclone External Drain System 494
H - Gas Analysis 504
I - Gasifier Heat Balance 5O9
J - Analysis and Estimation of Errors 522
K - Computer Programmes for Analysis 542
of the continuous run Data
L - Gasifier Product Composition 561
M - Batch Unit Procedure 567
N - Batch Data 57O
0 - Fuel Oil and Limestone Analyses 586
- v -
-------
LIST OF FIGURES
Page
1. Overall programme of work 8
2. Batch unit flow plan 15
3. Batch Unit Reactor 16
4. CAFB Pilot Plant Flow Plan 18
5. CAFB Revised Pilot Plant Flow Plan 21
6. CAFB Pilot Plant Flow Plan - Run 6 25
7. CAFB Pilot Plant Flow Plan - Run 7 27
8. CAFB Pilot Plant Sulphur Removal Efficiency 51
9. Vanadium Retention (Run 5) 54
1O. Sodium Retention (Run 5) 55
11. Nickel Retention (Run 5) 56
12. Size distribution of Fluid Beds (Run 5) 6i
13. Gasifier and Regenerator Fines below 62
6OO microns (Run 5)
14. Average Size of Bed particles (Run 5) 64
15. Heat Release vs Air/Fuel Ratio during Gasification 63
16. Sulphur Removal Efficiency vs Bed Depth (Run 6) 79
17. Sulphur Removal Efficiency vs Bed Sulphur (Run 6) 8O
18. Sulphur Removal Efficiency vs Bed Depth (Run 7) 81
19. Sulphur Removal Efficiency vs Bed Sulphur (Run 7) 82
2O. SRE vs Bed Depth, Runs 6 and 7 84
21 SRE vs Bed Sulphur, Runs 6 and 7 85
22. Cyclone Fines - BCR 1691 (Kerosene Combustion 1O5
870 deg. C.)
- vi -
-------
LIST OF FIGURES (Continued)
Page
23. Cyclone Fines - BCR 1691 (Kerosene Combustion lo5
1050°C, Fuel Oil Combustion 87O°C, Kerosene
Combustion 870°C on aged bed)
24. Cyclone Fines - BCR 1691, BCR 1359, Pfizer los
Calcite and Denbighshire (Gasification -
Regeneration Cycles)
25. Cyclone Fines - BCR 1359, Pfizer Calcite and lo°
Denbighshire (All Combustion conditions)
26. Cyclone Fines - Denbighshire (Kerosene Combustion lo7
87O°C on conditioned bed)
27. SRE during fresh bed tests on Amuay Vacuum Pipe- 110
still Bottoms
28. Carbon deposition during fresh bed tests on 11:L
Amuay Vacuum Pipestill Bottoms
29. SRE during fresh bed tests on High Sulphur Pitch 114
30. Carbon deposition on bed during fresh bed tests 115
on High Sulphur Pitch.
- vii -
-------
LIST OF TABLES
Page
1. Batch Unit Gas Analysis Equipment 17
2. Summary of Run 5 Operating Periods 31
3. Test Programme for Run 6 33
4. Factorial Plan, Run 7 36
5. Gasification Summary - Run 4 42
6. Operating Conditions during Run 5 Test Periods 50
7. Summary of Solids Loss - Run 5 $2
8. Silica/Calcium Oxide Ratios - Run 5 59
9. Nitrogen Oxides in CAFB Flue Gas 65
1O. Heat Release in CAFB Gasifier - Run 5 67
11. Product Gas Composition - Run 5 69
12. Summary of Gasifier Component Distribution 70
- Run 5
13. Summary of Regenerator Performance - Run 5 72
14. Averaged results for selected 1O hour periods 77
- Run 6
15. Averaged results for selected 1O hour periods 78
- Run 7
16. Results with Single Fuel Injector - Runs 6 and 7 88
17. Stone sulphur vs particle size - Run 6 91
18. Test Programme for CAFB Batch Units 92
19. Summary of batch unit SRE results 96
20. Summary of batch unit fines loss 98
- viii -
-------
LIST OF TABLES (Continued)
Page
21. Summary of batch unit Loss rates loi
22. Summary of batch unit calcination losses 102
23. Nature of Cylcone fines from batch unit studies 104
24. Comparison of Fuel Conradson Carbon Levels 109
25. Conditions for Tests plotted in Figures 27 & 28 112
26. Conditions for Tests plotted in Figures 29 & JO 113
27. CAFB Development Programme - Summary of 119
Engineering Effort
- ix -
-------
ACKNOWLEDGMENTS
The support of Esso Petroleum Company Limited is acknowledged
for the construction of a 293O kW (1O million BTU/hr)
Chemically Active Fluid Bed Gasifier facility at the Esso
Research Centre, Abingdon, Berkshire, England, and for its
use in the generation of continuous gasification data for
this project.
The authors would also like to thank Mr. O.K. Priestnall,
Mr. J. Buzzacott, Mr. D. Storms, Mr. J. Cocker and Mr. A.
Brimble for their strenuous efforts in generating the
experimental data on which this report is based.
Finally, they acknowledge the assistance given by other Esso
Petroleum Company personnel in operating the pilot plant, in
maintenance of equipment, and in chemical analysis of test
samples.
- x -
-------
SECTION 1
CONCLUSIONS
TASK I
1. Stability and•quality of continuous pilot plant
operations were greatly improved by modifications which
included uninterrupted limestone addition, regenerator
back pressure control, flue gas recycle scrubbing,
nitrogen quench for regenerator over temperature
protection, and a positive pressure pilot flame for
the main burner.
2. There are indications that prior to Run 6 the SO2 content
of the flue gas was dependent on its dust content. This
effect was eliminated in Runs 6 and 7.
3. No significant difference was found between the sulphur
removing abilities of BCR 1691 and Denbighshire stone
at comparable operating conditions in the continuous
pilot plant. There were however indications that BCR
1359 gave a better performance. Pure stones such as
Denbighshire and BCR 1359 are preferred to impure
stones such as BCR 1691 because they make less dust
and are less likely to sinter.
4. The effect of lime replacement rate on sulphur removal
efficiency diminishes rapidly as the Ca/S ratio is
increased above l.O and even when the Ca/S ratio is
reduced to O.5 an S.R.E. in the region of 70% is obtain-
able at a bed depth of 53 cm.
5. Increasing the gasifier bed depth does appear to improve
S.R.E. and the indications are that S.R.E's better than
85% should be obtainable at bed depths greater than 70 cms
6. S.R.E. appears to depend on the sulphur content of the
bed material which for good results should be less than
4% by weight in the gasifier bed.
7. On the limited evidence of Run 7, stone size appears to
have very little effect on S.R.E. On this evidence there
is no clear advantage in using a finer material than is
required to ensure adequate fluidisation at the optimum
superficial gas velocity within the gasifier bed.
8. The temperature of the gasifier bed appears to have a
relatively minor effect on S.R.E. within the range 870 -
920'C.
- 1 -
-------
9. Although poor sulphur balances were obtained during
Run 5, Runs 6 and 7 gave good sulphur balances which
were within the calculated margin of error.
1O. Regenerator performance in the continuous pilot plant
is sensitive to slight changes in reactor geometry.
Subsequent to Run 5 the distributor of the regenerator
was lowered by 1O cms in order to allow fluidising
air to be heated before meeting the incoming stone.
This resulted in a considerable improvement in
regenerator selectivity and an increase in SC>2
concentration in the regenerator off-gas.
11. During Runs 6 and 7 the air/fuel ratio at which the
gasifier was operated was always within the range
20 - 23% of stoichiometric. Within this range
variations in air/fuel ratio have no obvious effects
on S.R.E.
12. Combustion of CAFB gasifier product in the pilot
plant burner produces less nitrogen oxides (166 cm^/m^
(p.p.m.) average) than direct combustion of fuel oil
(263 cm^/m3 average).
13. During Run 5, 36% of the sodium in the fuel, 75% of the
nickel and virtually 1OO% of the vanadium was bound
by the bed material.
14. Self bonded silicon carbide is quite unaffected by the
conditions within the gasifier and gives very satisfactory
service. It has been used for the construction of the
gas outlet pipes from the gasifier cyclones.
15. Coke laydown at the cyclone entrances and within the
cyclone barrels is the factor which limits both the
duration of a continuous run of the unit under gasifying
conditions and the extent to which bed material is
retained by the cyclones. The coke can be removed by
a simple burn-out procedure and the longest period of
operation between such burn-outs/ in the runs covered
by this report, was of 211 hours duration. In a large
scale multi-cyclone unit it should be possible to
burn-out the gas ducts in rotation whilst the unit is
on stream.
16. Stainless steel cyclone liners are not satisfactory as
a means for providing a smooth cyclone surface. In the
pilot plant test they failed under decoking conditions
and provided a surface for increased carbon deposition.
- 2 -
-------
17. The heat release by fuel partial combustion in the
gasifier is approximately 7211 J/kg (3,100 BTU/lb) at
20% of stoichiometric air based on the fraction of
carbon and hydrogen oxidised and the amount of CO
produced.
TASK II
1. Lime from BCR 1691 stone produces much more dust
under comparable CAFB fluidisation conditions than
either of the higher purity limes: BCR 1359 and
Denbighshire.
2. Dust production with BCR 1691 lime is particularly
severe during combustion with kerosene at 870 deg. C,
the normal CAFB pilot plant start-up condition.
3. Kerosene combustion at 1O50 deg. C causes less dust
production than combustion at 87O deg. C both with
BCR 1691 and with Denbighshire lime.
4. The fine dust produced during 87O deg. C combustion
with BCR 1691 lime is sticky in nature and clings to
pipe walls and cyclone internals unless mechanical force
such as rapping is employed to dislodge it. Under
gasification conditions the dust is not sticky, and is
produced at a lower rate.
5. Pfizer calcite decrepitates during gasification/
regeneration cycling. This results in unacceptably
high dust losses.
6. There is little difference in the desulphurising
performance of all four stones which were tested
under batch operating conditions although Denbighshire
stone was marginally the best.
7. Carbon deposition on the stone appears to be related
to the Conradson carbon quality of the fuel oil. The
heavier fuel oils which were tested had Conradson
carbon values of 17% and 33% and gave higher rates of
carbon deposition than Amuay fuel oil (11% Conradson
carbon) which was used for the bulk of the work.
8. When the 33% Conradson Carbon fuel was used it was not
possible to bring down the carbon content of the bed
material to a level which would allow satisfactory
continuous regeneration even with air fuel ratios as
- 3 -
-------
high as 32% of stoichiometric. It follows that such
fuels will require a steam/air mixture for satisfactory
gasification, unless a large gasifier fitted with heat
exchangers is used.
TASK III
An engineering scoping study by Esso Engineering indicates
that total CAFB development through a 10O + MW demonstration
test period is expected to take about 6k years and require
$3,320,000 in engineering effort. Optimistically the
development time might be reduced to 4-fc years with a cost
of $2,52O,OOO, but risks associated with the large unit would
be correspondingly increased.
- 4 -
-------
SECTION II
RECOMMENDATIONS
1. Further work is required in order to clearly establish
the effects of the most important variables which have
emerged from this study.
1, Bed Depth
2, Bed Sulphur Content.
2. Only a limited range of superficial gas velocities has
been used in the work reported here and the effect of
raising the gas velocity to 1.83 m/sec (6 ft/sec) should
be explored.
3. A satisfactory cyclone fines drain and return system
should be installed prior to further tests.
4. Methods should be developed for the control of carbon
deposition in the gas ducts or alternatively for the
removal of deposited carbon under running conditions.
5. In all C.A.F.B. installations particular care must be
taken with the sampling of the boiler flue gas in order
to avoid errors in the measurement of SO2 concentration.
A high velocity hot flue gas system using a hot cyclone
and filter has given satisfactory results and is
recommended.
6. It is important to measure the dust producing
characteristics of candidate stones, especially under
start-up and hot standby conditions.
7. Attention should be paid to the possibility of
minimising stone consumption.
8. Attention should be paid to the effect of stone
replacement rate on the amount and composition of
stack dust emissions.
9. More evidence is required concerning the effect of stone
size on S.R.E. and it is recommended that future tests
should be planned to provide this information.
1O. An emergency regenerator quench system should be included
in CAFB installations to prevent sintering and
agglomeration by temperature upsets.
- 5 -
-------
11. Regenerator operation should be tested at lower air
rates to confirm if reduced CaS conversion level will
improve selectivity of CaS oxidation to CaO and reduce
the quantity of CaS04 returned to the gasifier.
12. Tests should be made to establish the effectiveness of
steam in gasifying carbon laid down on the gasifier bed
material by heavy fuel oil.
- 6 -
-------
SECTION III
INTRODUCTION
GENERAL
The Chemically Active Fluid Bed process is a means of
avoiding sulphur oxide pollution while using heavy fuel oil
for production of power. The process uses a fluidised bed
of lime particles to convert the oil into a hot, low sulphur
gas ready for combustion in an adjacent boiler. Sulphur
from the fuel is absorbed by the lime which can be
regenerated for reuse. During lime regeneration the sulphur
is liberated as a concentrated stream of S02 which may be
converted to acid or elemental sulphur.
Exploratory work on the CAFB began at the Esso Research
Centre, Abingdon (ERCA) in 1966. In 1969 a six-phase
programme of work was prepared to take the CAFB process from
the laboratory stage through to a demonstration of the process
on a 5O to 1OO megawatt power generation boiler located in
the United States. A summary of this six phase programme
is shown in Figure 1. Phase'I studies at Esso Research
Centre were funded under Contract CPA 7O-46 in June 1970,
and consisted of batch reactor fuel and limestone screening
studies, a variable study with U.S. limestone BCR 1691,
and initial operation of a pilot plant incorporating
continuous gasification and regeneration. The results of
these studies were described in the final report (Reference 1)
for that contract, dated June 1972.
This report covers work on the second phase of studies
carried out in the period July 1, 1972 through May, 1974.
GASIFIER CHEMISTRY
When heavy fuel oil is injected into a bed of fluidised lime
under reducing conditions at about 9OO deg. C, it vaporises,
cracks, and forms a series of compounds ranging from H2 and
CH4 through heavy hydrocarbons to coke. The sulphur
contained in the oil forms compounds such as H2S, COS and
CS2 with H2S predominating. The sulphur compounds react
with CaO to form CaS and gaseous oxides.
For examples
CaO + H2S » CaS + H20
- 7 -
-------
OVERALL PW06RAMME OF WORK TO ACHIEVE CONVERSION OF A 90 TO IQQ MW POWER GENERATION BOILER TO C A F B OPERATIC*
STUDIES
CNG'NEERINB
DESIGN
MILEN
COMVEMlON
I
00
I
CONSTRUCTION
BATCH
STUDIES
CONTINUOUS
(FEASIBILITY)
aOILCM .AWtlUWLE R* COHWCHSIOK.
IHMNCE TESTS
CONSTRUCT CONVEIISION
TO DESIGN AND COMMISSION
COMMITMENT ON 804LER
AVAILABILITY FOO CONVEftSlOM
COMMITMENT ON
OKRATM AVAILABILITY
MMSE OF
ACTIVITY
-------
The equilibrium for this reaction is far to the right.
With a fuel containing 4% sulphur the equilibrium permits a
desulphurising efficiency greater than 90% up to 11OO deg. C.
Other factors however limit gasification temperature to the
range of about 85O to 9OO deg. C where the equilibrium
sulphur removal would be about 99% (see Reference 1).
In the shallow fluidised bed of the gasifier there is a
rapid circulation of lime between top and bottom. Indications
are that coke is laid down on the lime in the upper portion
of the fluid bed by oil cracking and coking reactions and
that this coke burns off in the lower portion where oxygen
is supplied by the air distributor.
Gasification conditions of temperature and air-fuel ratio
must be chosen to maintain a balance between the rate of coke
and carbon deposition and the rate of carbon burnoff.
Broadly/ this balance is met at gasification temperatures in
the range of 850 to 9OO deg. C and air-fuel ratios around 20%
of stoichiometric. Lower air fuel ratios are operable at
the upper end of the temperature range/ and higher air-fuel
ratios are needed as temperature is reduced.
Much of the oxygen entering the gasifier is consumed in
oxidising coke to CO and C02 near the distributor. Of course/
some enters other regions of the bed where it reacts with H2
and hydrocarbons to form water and more carbon oxides. The
final product from the gasifier is a hot combustible gas
containing H2 hydrocarbons CO/ CO2/ H2O, and No. Most of
the energy released by partial combustion of the fuel is
retained by this gas as sensible heat.
Only a portion of the CaO in the lime is reacted on each pass
of solids through the gasifier. Good sulphur absorption
reactivity has been obtained with up to 20% of calcium
reacted in single cycle batch reactor tests, but in the
continuous unit, the average extent of calcium conversion
to sulphide is held to less than 10%.
When a single batch of lime is cycled between gasification
and regeneration conditions it gradually loses activity for
sulphur absorption. The activity of the bed can be maintained
if some of the lime is purged each cycle and replaced by
fresh material. Reactivity of the bed is therefore a function
of the lime replacement rate. The replacement lime is usually
added to the gasifier as limestone which calcines in situ.
- 9 -
-------
Vanadium from the fuel oil deposits on the lime during
gasification. Experimental evidence is that practically all
of the fuel vanadium can remain fixed with the lime.
REGENERATOR CHEMISTRY
Calcium sulphide is regenerated to Calcium oxide by air
oxidation.
CaS + 3/2 02 > CaO + S02
AH = -458.1 kJ/mol
A competing reaction also consumes oxygen and forms calcium
sulphate.
CaS + 2 O2 ^ CaS04
AH = -921.3 kJ/mol
Both reactions are strongly exothermic. A third reaction
between the solid species is also possible.
CaS + 3CaSO4 > 4CaO + 4S02
AH = 926.8 kJ/mol
This reaction is strongly endothermic.
The equilibrium constants (Appendix A, Reference 1) for these
reactions determine the maximum partial pressure of S02 which
can exist in equilibrium with mixtures of CaS, CaO, and CaSO4
at any given temperature. These equilibria also determine a
relationship between regenerator temperature and the maximum
theoretical selectivity of oxidation of CaS to CaO.
At low oxidation temperature, the equilibrium S02 partial
pressure is too low to permit all the oxygen supplied to leave
in the form of S02. The excess oxygen then goes to form
CaSO^. Experimental oxidation selectivities are lower than
the theoretical maximum, probably because of contacting and
kinetic factors.
Since each sulphided lime particle passes through a range of
temperatures and oxygen concentrations during its transit
through the regenerator, it is exposed, on average, to less
favourable selectivity conditions than those at the top of
the bed.
- 10 -
-------
Calcium sulphide oxidation selectivities to CaO of 70 to 80%
and regenerator SO2 concentrations of 8 to 10% have been
achieved in pilot plant operations at regenerator temperatures
in the range of 1040 to 1070 deg. C.
During the conversion of CaS to CaO and CaSO4 there is
evidence for existence of a transient liquid state (Reference
2). If air is passed through a hot static bed containing CaS,
some of the particles will agglomerate into lumps during the
regeneration reaction. Agglomeration does not occur if the
bed is vigorously fluidised.
PREVIOUS EXPERIMENTAL WORK
A basis for the CAFB process had been established by
experiments in 17.8 cm (7-inch) i.d. batch reactors at ERCA
prior to 1970.
During 1970, two new batch reactor units were constructed
for the OAP contract. Work in these batch units established
the suitability for CAFB of a Venezuelan fuel oil available
in the U.S., and selected the better of two U.S. limestones
suggested by OAP. Both of the U.S. stones, BCR 169O and
BCR 1691, were lower in CaO content than the U.K. stones
tested previously. In cycle tests the BCR 1691 stone gave
sulphur removal activity comparable to that of the higher
purity U.K. stones at equal Ca/S ratios. The BCR 169O stone
was found to be unsuitable in three respects. It gave lower
sulphur recovery at equal Ca/S ratio; it attrited badly; and
it sintered and agglomerated during regeneration. The BCR
1691 stone therefore was selected for further study. During
1971 an intensive study of gasification variables was
conducted in the batch reactors with this stone. Tests with
fresh beds screened the effects of major variables including
air fuel ratio, gasification temperature, bed depth, lime
particle size, and gas velocity in the bed. The variables
of lime replacement rate and extent of calcium reaction
between regenerations were probed in cyclic tests where the
lime was cycled between gasifying and regeneration conditions
in the batch reactors.
These studies provided the basis for a number of guidelines and
process correlations. The effects of bed depth (25 to 51 cm)
(1O to 2O inches) and fluidisation velocity (1.22 to 2.44 m/sec)
(4 to 8 ft/sec) were correlated as gas residence time in the
bed, giving an approximately first order sulphur removal
rate expression. Sulphur differential, the quantity of sulphur
to which the lime was exposed in each gasification cycle,
- 11 -
-------
emerged as an important variable. As an approximation lime
reactivity varied inversely with the square of this
differential and increased directly with lime to sulphur
replacement ratio.
In parallel with the batch unit experiments, ERCA constructed
a pilot plant in which the gasification and regeneration
reactions could be studied under continuous operating
conditions. A 2930 kW (10 million Btu/hr) water cooled
boiler was included in the system to burn the gasifier product
and dispose of the heat. Three tests designated CAFB Runs
1, 2 and 3 were made in this pilot plant during 1971. Run 3
lasted 230 hours of which 2O4 were at gasifying conditions.
Denbighshire limestone (UK) was used throughout these runs
together with Venezuelan fuel oil containing 2.5% sulphur.
The pilot plant successfully demonstrated many features of
the process including sulphur removal, lime regeneration,
temperature control, start up, shut down, solids circulation,
and release of the sulphur as a rich (8-lO%) stream of S02.
It also pinpointed areas for improvement which included
reduction or elimination of carbonaceous deposits in cyclones
and gas transfer ducts, minimisation of fines production and
losses into the boiler, and improvement of regenerator
oxidation selectivity.
WORK OBJECTIVES
Work on this contract constituted the second phase of a six
phase programme to demonstrate and evaluate the CAFB gasifier
on a commercial scale with a power plant boiler. Work on
this phase consisted of three tasks.
Task I was operation of the CAFB pilot plant with the
following set of objectives.
a. Verify that continuous gasification, sulphur and metal
removal and lime regeneration results are as batch
studies have indicated and evaluate the effects of bed
depth, velocity, fuel/air ratio, lime make-up and fuel
rate.
b. Determine minimum excess air requirements for operation
of a continuous regenerator with good temperature
control and maintenance of a low residual concentration
of sulphur on the lime bed.
c. Demonstrate operability of the process over a prolonged
period of time to show that accumulation of fines,
agglomerates, carbon or other deposits do not interfere
with continuous operation.
- 12 -
-------
d. Demonstrate means of preventing or removing deleterious
accumulations of tar or carbon from gasifier and transfer
duct internals.
e. Determine effects of number and location of fuel injectors
on gasification, sulphur removal, and carbon content of
gasifier lime. Include operation with single oil
injector passing through the air distributor.
f. Test and demonstrate means of process start-up, shut-
down, turndown and control. Determine maximum turndown
ratio with independent control of gasifier and
regenerator variables.
g. Determine effect of regeneration temperature on the
maintenance of lime activity.
h. Study the existing burner operation with CAFB gasifier
product. Establish operability with high gas velocity,
measure flame characteristics, efficiency of combustion,
production of NOx, and flame stability.
i. Under conditions of lined out operation with equilibrated
lime, measure SO2 removal in the regenerator and
determine rate of lime attrition and particle size
distribution of solids carried over from the gasifier
and regenerator. Determine engineering properties of
equilibrium solids such as fluidized bed density,
minimum fluidization velocity and particle size
distribution.
Four pilot plant runs were planned to accomplish these
objectives. To continue the numbering system begun in Phase
I, these runs are designated runs 4, 5, 6 and 7.
Task II was an evaluation of additional limestones with two
new fuel oils in batch reactor experiments conducted between
continuous unit runs. One of the test oils was a high
sulphur residue by-product of gas oil desulphurisation, the
other a high sulphur pitch. Originally, four new stones
were to be studied. Because of factors uncovered during
the first pilot plant run, the batch unit programme was
modified to include measurements of dust production tend-
encies of the stones under combustion conditions and to
reduce the number of stones to be investigated to three.
- 13 -
-------
Task III was a definition and assessment of the scope of
engineering effort required to move the CAFB from the pilot
plant stage through the development stage including the
demonstration unit.
Tasks I and II were completed at the Esso Research Centre
Abingdon, England. Task III was conducted by the Esso
Research and Engineering Co., Florham Park, N.J., U.S.A.
REPORTING AND DISCUSSION OF RESULTS
During the performance of Task I the objectives for Task II
were modified as a result of information generated during
the first continuous gasifier run under Task I. Consequently,
the reporting and discussion of results of Tasks I and II is
set out in Sections V and VI in chronological order, so that
the sequential logic of changes to objectives, equipment
and techniques can be readily followed.
- 14 -
-------
SECTION IV
DESIGN AND CONSTRUCTION OF EQUIPMENT
GENERAL
The experimental equipment used in this study consists of two
batch reactor units and the continuous CAFB pilot plant.
These units have been described (Reference 1) previously in
detail. For the current work, the batch units remain
essentially unchanged. However several modifications were
made to the pilot plant on the basis of experience gained
in the first three runs.
BATCH UNITS
Each batch unit contains a reactor, air and fuel systems,
flare for product gas disposal, and gas sampling and analysis
system as shown in the flow plan, Figure 2.
Flora
Sample Gas
to
Anolytert
Sample Go*
Pump
S
i Sample
Ftomt
CAFB
Batch Reactor
Air Blower
Air Meter
From Heated
Oil Drum
Feed
Wtigh-tonk
Fuel Injector Air
Propant for start-up
FIGURE 2 Batch Unit Flow Plan
- 15 -
-------
A reactor is illustrated in Figure 3.
•ilw «•*'••« ftilfil tilii
»»• tl Bill*! Mil
Irt Inli
•IMrlkdttr riltl
•umur/ TMrMMlMi
FIGURE 3 Batch Unit Reactor
The reactor is of refractory lined carbon steel construction.
The lower section, which contains the fluid bed, is 17.8 cia
(7 inches) i.d. by 83.8 cm (33 inches) high. The upper
section is expanded to reduce gas velocity and is non
symmetrical to permit internal cyclones to drain externally.
The plenum beneath the gas distributor is also refractory
lined to serve as a combustion chamber for propane-air
mixtures used during unit start up. The distributor is a
"top hat" shape cast refractory design. The central raised
section, 12.7 cm (five inches) in diameter, contains 16
horizontal holes around its circumference.
- 16 -
-------
For the current work, a rapper was installed on one cyclone
in each reactor to prevent fine particles sticking to the
cyclone walls. The pneumatic activator of the rapper is
located outside the reactor and drives a striker rod through
a gland to tap on the cyclone wall.
The gas analysis equipment used in this study is the same as
used in Phase I, and is summarised in Table 1. Full details
are given in Appendix H.
Table 1
Batch Unit Gas
Analysis Equipment
Manu-
Analyser
S02
S02
S02
C02
CO
02
Type
Infra-red
Infra-red
Conductimetric
Infra-red
Infra-red
Paramagnetic
facturer
Maihak
Maihak
Wostoff
Maihak
Maihak
Servomex
Model
Unor 6
Unor 6
—
Unor 6
Unor 6
OA 137
Response
Range
(ppm)
0-20% by vol.
0-10OO cm3/m3
(ppm)
0-20% by vol.
0-20% by vol.
0-25% by vol.
- 17 -
-------
CONTINUOUS PILOT PLANT
Process Flow Plan
Figure 4 is a process flow plan of the continuous pilot plant.
The heart of the system is the gasifier-regenerator unit cast
of refractory concrete contained in an internally insulated
steel shell. The product gas of the gasifier fires a 293O kW
(1O million Btu/hr) pressurised water boiler. The hot water
is heat exchanged with a secondary water circuit which loses
its heat through a forced convection cooling tower. The rest
of the system consists of the necessary blowers, pumps and
instruments to operate the gasifier, regenerator, burner and
solids circulating system.
Oil
Storog*
Combultion Air Blovtr
Htjtruroter
Limt Drain
rH««ntrotor Air BlOwtrt
Propani for
Start-up
FIGURE 4 CAFB Pilot Plant Flow Plan
The gasifier itself sits within a pit to permit alignment of
the gasifier outlet duct with the burner inlet. Fuel pumps,
flow meters, and start up burner controls are mounted on a
mechanical equipment console. Electrical instrumentation
and manometers are mounted on a separate control console.
Gasifier blowers are located in a separate blower house
outside the main building, and the cooling tower is mounted
on the roof.
- 18 -
-------
The gasifier and regenerator reactors are cavities in a
single refractory concrete block. The block contains other
cavities which make up the gasifier outlet cyclones, the gas
transfer ducts, and the transfer lines through which solids
circulate between gasifier and regenerator. The gasifier
cavity is rectangular in cross section, tapering from 44.5 x
94 cm (17.5 x 37 inches) at the distributor level to 49.5 x
99 cm (19.5 x 39 inches) at the 53 cm (21 inch) level. The
upper portion has parallel sides. The regenerator tapers
from 17.8 cm (7 inches) diameter at the bottom to 2O.3 cm
(8 inches) diameter 55.9 cm (22 inches) above distributor
datum and remains parallel thereafter. A full description
of the unit is given in Reference (1), pages 2O-28.
PILOT PLANT MODIFICATIONS
The operation of the pilot plant in Runs 1, 2 and 3 showed
the need for improvement in some areas. Changes were made
to various sections between test runs as a result of
experience and other changes were made to achieve specific
objectives.
Modifications prior to Run 4
A new system of feeding limestone to the gasifier was
constructed to provide continuous monitoring of the limestone
feedrate and also enable the feed hopper to be refilled from
an upper lock hopper without disturbing the stone feed into
the gasifier.
An additional blower was installed to boost the flue gas
recycle supply to the main blowers for the gasifier and a
cyclone was installed in the main flue from the boiler to
the stack.
The earlier test runs had illustrated the importance of
pressure balancing the regenerator and gasifier pressures and
an automatic pressure balancing valve was installed into the
regenerator offgas line.
The gasifier was modified to include silicon carbide cyclone
outlet tubes in place of the double wall stainless steel
tubes with steam cooling used on Run 3. The regenerator
distributor design was modified from a refractory construction
which had a tendency to crack, to one with stainless steel
nozzles protruding through a layer of refractory. This
principle of distributor design had been proven on the
gasifier distributor although the operating temperature was
lower than the regenerator application.
- 19 -
-------
The stainless steel nozzles in the gasifier distributor were
modified to provide a low gas exit velocity to minimise
damage to the bed material. The design utilised the original
nozzle but included an additional outer ring to provide a
staggered path for the outlet air before emerging through
large holes at a lower velocity. This design still maintained
the original nozzle pressure drop characteristic because of
the retention of the original small diameter holes.
The bifurcated duct connecting the cyclone outlets to the
burner was rebuilt with swept bends at the changes in duct
direction to minimise the deposition of lime and carbon
shown in the earlier runs.
Modifications prior to Run 5
Before Run 5 a number of modifications were made to the pilot
plant to permit improved operations with a dusty limestone.
The major changes were:
• External cyclone drainage
• Non obstructing regenerator pressure control system
• Flue gas recycle scrubber
• Regenerator overtemperature quench
• Flue gas stack scrubber
• Cyclone liners
Other minor changes were made to the unit to improve pilot
flame stability and to assist in diagnosing boiler
performance. The revised flow plan is shown in Figure 5.
Cyclone External Drain System
Pressure balance calculations on the gasifier cyclone return
system indicated that there would be insufficient height of
leg available to return fines to the gasifier through the
internal passages if bed depth were increased to the levels
desired for high sulphur recovery with low replacement rates
of BCR 1691 stone. This problem increases in severity when
fouling increases the pressure drop across the cyclone inlet.
By using external cyclone drains, the pressure at the cyclone
drains could be made independent of the gasifier bed pressure.
It was not sufficient however just to drain the cyclones
- 20 -
-------
Cooling Tower
Water
i T~!
Heat Exchanger
—To Preasurisation
Unit
FIGURE 5 CAFB Revised Pilot Plant Flow Plan (Run 5)
-------
externally. With deep beds the rate of entrainment into
the cyclones could be high and stone losses severe unless
the coarse fraction were returned to the gasifier. There-
fore an external system to both drain the cyclones and
return the fines was needed.
After consideration of several designs, a system was selected
which met the constraints of available space, pressure, and
gas consumption. Details of the system appear in Appendix G.
In summary the system for each cyclone consists of a conical
bottom pot receiver mounted beneath each cyclone drain, a
butterfly valve to isolate the pot from the cyclone when the
pot is being emptied and a Warren Springs Laboratory pulsed
flow powder pump to transfer solids from the conical pot to
an overhead receiver, common to both cyclones. An elutriator
removes the very fine fraction from the cyclone solids, and
a pneumatic injector returns the larger size fraction to the
gasifier bed. Nitrogen is the operating gas for the transfer
system. Most of the time the butterfly valve beneath the
cyclone remains open draining solids to the conical pot. At
timed intervals the butterfly valve closes and the pot is
pumped out to the overhead receiver.
Regenerator Pressure Control
To avoid a repetition of the regenerator off gas line blockage
which terminated Run 4, the pressure control valve was removed
from the outlet line. This valve had become blocked by fine
solids in the gas stream during that run. In order to regulate
regenerator pressure a blower was fitted which injected air
downstream of the cyclone outlet. Air flow from this blower is
requlated by control loop which senses the difference between
gasifier and regenerator pressure and adjusts a valve in the
air line to achieve the desired pressure difference.
Flue Gas Recycle Scrubber
Run 4 demonstrated that simple cyclones were unable to provide
sufficient cleaning of the recycle flue gas stream to prevent
gradual blockage of the gasifier air distributor nozzles. A
venturi scrubber system was designed to provide greater clean-
up. The scrubber was designed to handle 34O m3/hr (2OO CFM)
of gas at a pressure drop of 3.48 kPa (14" w.g.) Water is
sprayed into the gas at the throat of a venturi. A knockout
vessel at the venturi outlet removes the water and entrained
dust. The venturi wa% placed on the suction side of the
recycle blower to protect the blower from dust, and a
recycle line was provided to permit a high gas circulation
rate through the venturi even at low rates of flue gas flow
to the gasifier.
- 22 -
-------
Regenerator Quench
The circulation of fresh solids from the gasifier to the
regenerator controls regenerator temperature. Upsets in
the pressure balance between gasifier and regenerator or
temporary obstructions in one of the solids transfer lines
can sometimes interrupt this solids circulation and allow
regenerator temperature to increase.
If regenerator temperature gets too high there is danger of
sintering the lime particles and forming agglomerates. An
emergency quench system was installed to prevent this
occurrence. The lower regenerator bed thermocouple was
connected to a controller which admits a flow of nitrogen
to the intake of the regenerator air blower when bed
temperature reaches the alarm point. The alarm was set to
operate at 110O deg.C. Nitrogen fed to the blower dilutes
the regenerator air supply and reduces the rate of oxidation
to prevent over temperature. The circuit is fitted with a
manual switch so that the process operator can inject
nitrogen at will in the event of other forms of upset.
Stack Top Gas Scrubber
To avoid particulate emissions to the atmosphere during
periods of high lime losses from the gasifier cyclones, a
final stage of water scrubbing was added to the pilot plant
flue gas stack. Experience in Run 4 had indicated that the
flue gas cyclone was not completely effective in recovering
lime fines produced from BCR 1691 under combustion conditions,
The new scrubber consists of a section of ductwork shaped
like an inverted "U" mounted on top of the stack. The down
leg directs the gases into the top of a funnel shaped
receiver which causes another reversal of gas direction
upward to the atmosphere. Water is sprayed into the down
leg and collected by the funnel. This water which picks up
limedust by passage through the flue gas is conducted to a
ground level settling vessel. Overflow from this vessel is
circulated back to the scrubber nozzle by a centrifugal pump.
The system is designed to circulate water to the scrubber at
a rate of approximately 27 m3/hr (1OO gallons/min).
Modification prior to Run 6
The poor performance of the regenerator in Run 5 may have
been partly caused by the absence of fines which previously
had been returned from the right hand cyclone into the
- 23 -
-------
regenerator. It was decided therefor in Run 6 to reinstate
this internal transfer line for the right hand cyclone.
The pressure vessel transfer system which had been used on
the right hand cyclone was modified to act as a hot limestone
ejector to reduce carbon and lime deposits in the cyclone
entries. Figure 6 shows the modified flow plan and it will
be seen that hot bed material could be drained from the
gasifier and then ejected at a controllable frequency into
either left or right hand cyclone entries. In addition to
this change, other modifications were made to improve
operability of the transfer system by installing perforated
stainless steel plates within the conical transfer vessels to
retain the flakes of carbon and lime which earlier runs had
shown to choke the transfer pipes.
The regenerator distributor position was lowered with respect
to the transfer port ducting material from the gasifier so
that fresh material entering the regenerator would enter into
a hotter zone with a possible improvement in selectivity.
The distributor was lowered by inserting a silicon carbide
ring into the regenerator plenum.
The fuel injection system was extended to provide a further
injector through the gasifier distributor with one single
outlet hole set to discharge fuel horizontally into the bed.
The injector could be retracted into the distributor when
not in use.
The piping was arranged so that the total fuel supply would
be fed into the unit either totally or partially through the
bottom injector and side injectors. The gasifier plenum was
sub-divided into two sections in the ratio of 1:2 and by
individually controlling the air to the two plenums it was
possible to produce different velocities in the bed area and
induce more rapid mixing across the width of the bed.
Modifications prior to Run 7
The major changes made prior to Run 7 were associated with
the two distributors and the regenerator cyclone fines
system. The gasifier distributor was modified to include
two direct heat transfer water cooling tubes for bed
temperature control instead of flue gas recycle. In addition
the fuel injector through the centre of the distributor was
modified to include six outlet holes around its periphery
instead of one large outlet used in Run 6 in an attempt to
improve single injector performance.
- 24 -
-------
PS
Cooling Tower
~ Soft Water
IBH
i_ Heat Exchanger
}— To Pressurisation Unit
Fuel Oil
i
ro
FIGURE 6 CAFB Revised Pilot Plant Flow Plan (Run 6)
-------
Also the gasifier nozzle design was changed to the
original straight path high velocity exit type because the
staggered path low velocity design did not provide any
evident improvement.
The regenerator distributor was changed to the top hat design
used in the Batch unit test programme and Runs 1, 2 and 3 of
the continuous unit programme. After the good performance of
stainless steel in distributor designs, it was decided to
make this distributor in stainless steel and so eliminate the
unreliable performance of this component in refractory.
The fines collected in the regenerator cyclone had in all
earlier runs been drained externally and discarded. It was
considered useful if the unit could be modified to provide
the facility to return these fines into the gasifier via
the elutriator and air injection system which handled the
fines from the external cyclone drainage system. The modified
flow plan is shown in Figure 7.
- 26 -
-------
p—iCooling Tower
—•—& Soft Water
Kl
•J
Exchanger
—~• To pressurisation Unit
Stack
Flue Gas
Recycle
Air
Direct Heat Transfer
Water Tubes
FIGURE 7 CAFB Revised Pilot Plant Flow Plan (Run 7)
-------
SECTION V
PROGRAMME OF WORK
GENERAL
The programme of work consisted of three tasks - Task I,
operation of the continuous CAFB gasifier in four runs
(numbered four to seven), Task II, study of additional
limestones and fuel in batch gasification units, and Task III,
scoping of the engineering effort needed to take the CAFB
process through to a 10O megawatt (electrical) scale
conversion of a commercial power generation boiler.
As originally envisaged these three tasks were entirely
separate, i.e. there was no intention of selecting limestones
or fuels tested as part of Task II for use in Task I of this
phase of studies. However, the first run in Task I, Run 4,
identified severe operational problems in the form of gas
line plugging by very sticky fines* and as a result Task II
was modified to allow for an examination of the problem of
fines formation. The final programme of work carried out
under each task is set out below.
TASK I
Four runs were carried out in the 293O kW (10 million BTU/hr)
continuous CAFB gasifier. In each of these runs not only the
work objectives were different, but also the configuration of
the gasifier itself, since at this stage in a development
project the pilot plant serves as a means for gathering
data under realistic operating conditions and also provides
an opportunity for evaluating new equipment, configuration
and operating methods.
Run 4
The experimental plan for Run 4 called for use of limestone
BCR 1691 at a series of pilot plant conditions to test
correlations based on batch unit studies. Limestone replace-
ment rate, gasifier bed depth, and gasifier bed temperature
were the major variables to be examined. A brief test of the
effect of regenerator excess oxygen content was also included
in the experimental plan.
- 28 -
-------
A major goal of the study was to find if increasing gasifier
bed depth would have the beneficial effect that batch
studies had indicated to be possible. As events developed,
properties of limestone BCR 1691 prevented accomplishment of
these test goals and focussed attention on development of
means to start up and operate with a stone which produces a
great deal of dust under certain conditions.
The dust forming characteristics of this stone under full
combustion conditions were found to be much worse than had
been encountered with Denbighshire stone. This high rate of
fines production caused a number of operating problems,
extended the start up period, and eventually caused termination
of the run after nine hours of gasification. The start-up
and operational problems and data are listed in Appendix A,
and results are discussed in Section VI.
The con figuration of the unit during Run 4 is fully described
in Section IV, but essentially the gasifier was set up in the
same manner as for Run 3, with minor changes to equipment such
as improved stability of control over stone feed and with-
drawal from the unit and pressure balance between the gasifier
and regenerator, improved gas flow in the ducts to the burner,
more durable cyclone outer tubes and modified air
distributors in both gasifier and regenerator. The
ventilation and dust extraction facilities were also improved
in view of the potentially hazardous nature of the BCR 1691
limestone, which contains a significant amount of silica.
Run 5
Objectives of Run 5 were to measure sulphur removal efficiency
at different bed levels and lime replacement rates, to test
feasibility of desulphurising gasification at temperatures
above 900 deg. C approaching adiabatic conditions, and to
determine effectiveness of pilot plant modifications in
solving problems met in Run 4.
The test programme was to start up with precalcined lime from
Denbighshire stone, operate for a test period with
Denbighshire stone, and then switch to BCR 1691 stone.
Provision was allowed for returning to Denbighshire stone if
the BCR 1691 proved inoperable.
In actual fact, Denbighshire stone was used during the first
two days and the final week of operation. BCR 1691 was used
for the rest of the run.
- 29 -
-------
Table 2 summarises the various periods of operation during
the run. For purposes of computer identification of data,
each run hour is designated by a decimal number with its
whole part signifying run day and its fractional part the
hour. February 6 was run day 1.
For example, 4.163O, represents 4.3O p.m. on February 9. The
same system is employed on the abscissa representing time in
the data graphs of Appendix B. These graphs show the
variation with time of major operating variables during the
run. Tables of detailed operating data also appear in
Appendix B, together with a log of the run and the post-run
inspection. Results are discussed in Section VI.
The configuration of the unit for Run 5 is fully described
in Section IV. Between Runs 4 and 5 a number of modifications
were made to the pilot plant to permit improved operations
under conditions like those encountered in Run 4. The
experience of Run 4 and data gained in the batch unit
programme revealed that operation is more difficult with
limestone BCR 1691 than with Denbighshire stone. The batch
work indicated that BCR 1359, another high purity stone,
should behave more like Denbighshire stone. However there
are many locations where high purity limestone will be
considerably more expensive than lower purity stones available
locally. It therefore was desirable to assess more fully the
consequences of operating with a lower purity stone. Although
BCR 1691 is not necessarily typical of all low purity stone,
it has deficiencies which, if overcome, would assure that the
CAFB gasifier could operate with stones of a wide quality
range. Five major changes were made to assist operations with
the dusty and more easily agglomerated stone.
e External cyclone drainage
• Non obstructing regenerator pressure control system
• Flue gas recycle scrubber
• Regenerator overtemperature quench
• Flue gas stack scrubber
• Cyclone liners
Other minor changes were made to the unit to improve pilot
flame stability and to assist in diagnosing boiler performance.
- 30 -
-------
Table 2
Stannary of Sun 5 Opergttay. Periods
Pates
Feb 6 - Feb 9
Feb 9 - Feb 11
I
Feb 13 - Feb 14
1 Feb 16 - Feb 18
Felx 21 - Feb 22
Feb 25 - Feb 27
Feb 28 - March 3
Run Days
1.2OOO-4.O5OO
4.0500-6.1OOO
8.192O-9.O63O
11.1215-13.1000
16.0600-17.2200
20.1800-22.1900
23.1300-26.1900
Limestone Feed
Number of Test Gasification
Periods
Hours
Denbighshire
BCR 1691
BCR 1691
BCR 1691
BCR 1691
Denbighshire
Denbighshire
2 )
)
2 )
)
O
4
2
4
5
109
11
45
40
49
78
(
{
(
(
{
Cause of Termination
Pressure drop through
boiler.
Change to BCR 1691
caused no. interruption
of gasification.
Regenerator Defluidisation
Fuel Injector Failure
Regenerator Defluidisation
Cyclone Inlet Pressure Drop
Voluntary - End of Run
-------
Of the changes made the most significant was the introduction
of an external cyclone fines drainage and return system.
Previously the cyclone fines had been returned partly into
a stream of regenerated stone flowing from the regenerator
to the gasifier, and partly into a stream of stone flowing
from the gasifier into the regenerator. No data is
available on the mass flows for the cyclone fines via each
route, but it is reasonable to assume them to be equal.
Thus half the gasifier fines trapped by the gasifier cyclones
were fed directly into the regenerator.
Under the revised configuration all cyclone fines were fed
directly into the gasifier itself, hence it was recognised
that there was a possibility that these fines would be
stripped from the bed before reaching the catch pocket for
the gasifier to regenerator bed circulation line, and
consequently these fines would not enter the regenerator at
any time, but would recirculate around the loop: gasifier
bed-gasifier cyclones-fines return to gasifier bed. In time
attrition would result in these fines being reduced to such
a small size that they would enter the boiler - their only
route for escape from the loop. To avoid the possibility .
an elutriator was installed in the fines return line to
allow selective removal of fines.
Run 6
The experimental plan for Run 6 was intended to provide
information in the following areas:
• Performance of Limestone BCR 1359
• Fuel injector number and location
• Regeneration
• Reduction of .solids deposits in gasifier cyclones
and ducts.
To obtain this information, the programme of test conditions
shown in Table 3 was proposed. The first four tests were
aimed specifically at finding the best set of regeneration
conditions for the subsequent gasifier tests. The effects
of excess oxygen level and temperature were to be tested with
constant gasification conditions. Also by comparing overall
results with those of Run 5 it was intended to determine if
returning half the gasifier fines to the regenerator
produced a more effective regenerator operation.
- 32 -
-------
Table 3
Test Programme for Run 6
Test
No
1
2
3
4
5
1 6
to
U) 7
1 8
9
1O
11
Air/Fuel
Ratio
(% of Stoich)
20
«
II
•
H
It
m
m
m
»
•
Gas Velocity
(Gasifier)
(ra/sec)
1.22
N
•
n
m
m
m
-
•
«t
•
Gasifier
Temp
CO
870
M
II
N
N
•
M
II
"
II
Limestone Gasifier
Particle size Bed death
(u) (cm)
6OO - 3OOO 69
69
69
69
51
69
51
69
69
69
69
Make-up
Rate
(mol CaO/mol s>
1.0
1.0
1.0
1.0
l.O
1.5
1.5
0.5
l.O
1.0
1.0
Regenerator
Temperature
CC)
1050
105O
109O
1O9O
(a)
N
•
H
M
H
M
Regenerator
Excess O2
(% by vol)
O
1.0
1.0
O
(b)
•
M
N
M
H
H
Number of Fuel
Fuel Injectors
and Position
3 (normal/side)
UN N
• • •
• II *
MM •
• H H
• N N
UN •
• M M
1 (high/side)
1 (plenum)
(values for (a) and (b) to be decided after Test 4)
-------
The next set of five tests .was to provide additional
information on the effects of bed depth and limestone
replacement rate on sulphur removal efficiency. Two depths
and three lime replacement rates were to be used.
Regeneration conditions for these tests were to be selected
on the basis of the results of the first four tests.
The final two tests consisted of a study of the use of a
single fuel injector. Both a high level, side entering
injector and a bottom entering, variable level injector were
to be tested.
The investigation of a means to reduce cyclone inlet fouling
was to continue throughout the run. The method under trial
was the injection of gasifier bed solids into the cyclone
inlet. At first, only the left cyclone was to be treated
with the right cyclone untreated as a control. If the
method proved successful in keeping the left cyclone inlet
clear while the right one fouled, the solids injector would
be transferred to the right side to see if it would clean a
fouled inlet.
Precalcined Denbighshire lime and used bed removed from
Run 5 was to be used to establish the initial fluidised bed
during startup. Stone feed would then be switched to BCR 1359
for the remainder of the tests.
The configuration of the unit for Run 6 is fully described in
Section IV. Modifications from the Run 5 configuration were
made in the areas of fuel injection, plenum air distribution,
cyclone fines return, boiler flue gas sampling, regenerator
distributor location, and cyclone lining.
To permit tests of fuel injector location two new fuel
injectors were installed and provision was made for piping
the total fuel input to one, two or three injectors. One of
the new injectors entered the bed vertically through the
distributor. The other new injector entered through the side
at a higher elevation than the original three injectors.
The air distributor plenum was subdivided to permit a
variation in air supply rate in two different sectors. This
arrangement was to permit a test of the effect of increasing
solids circulation rate in the vicinity of the fuel injector
when a single injector was employed.
- 34 -
-------
The right hand gasifier cyclone was changed back to the
original configuration so that fines were drained to the
regenerator. The other cyclone remained as it was in Run 5
returning its fines to the gasifier by an external transfer
system. A system to circulate solids from the gasifier bed
to the left hand cyclone entry at a controlled rate was
installed. This equipment was to test the effect of coarse
solids injection on reduction of fouling in the cyclone inlet.
A new sampling system was installed at the rear of the boiler
to increase reliability of the flue gas analysis. A large
flue gas sample was to be withdrawn from the boiler through a
hot cyclone to remove most of the dust. A smaller sample
then would be drawn through a hot filter to remove residual
dust before passage through a condenser to the analysers.
A high density silicon carbide liner was fitted to permit
mounting the regenerator air distributor four inches lower
than its former position. This arrangement was intended to
increase regenerator residence time and provide a greater
vertical separation between the air entry and solids entry
points. The opportunity this provided for the air to be
heated before meeting fresh sulphided solids was intended to
improve selectivity of CaS oxidation to CaO and S02.
Stainless steel cyclone wall liners which had been tested
in Run 5 proved to be unsatisfactory and were removed. The
cyclone walls were treated by application of a layer of
castable refractory to reduce surface roughness.
Run 7
The experimental programme for Run 7 was aimed at clarifying
the differences between sulphur removal efficiencies observed
in Runs 3 and 6. It was not possible to use data from Runs 4
and 5 to resolve these differences because of operational
problems with Run 4 and data inconsistencies in Run 5.
The first test condition in Run 7 was selected to match
conditions studied in Run 3, and the different test
programmes were planned to take account of the two possible
results: test sulphur removal efficiencies in Runs 3 and 7
were the same, or that- Run 7 gave a lower efficiency than
Run 3. The programmes differed only in the actual levels
set for the major variables of bed depth and stone replacements
rate. These were to be varied, together with air/fuel
stoichiometry and bed temperature, in a factorial experiment
as set out in Table 4.
- 35 -
-------
Table 4
Factorial Plan, Run 7
Test Bed Depth Stoi chic-met ry Bed Temp. Feed Rate
1 H H L H
2 H H L L
3 H H H H
4 H H H L
5 H L L H
6 H L L L
7 H L H H
8 H L H L
9 L L L H
10 L L L L
11 L L H H
12 L L H L
13 L H L H
14 L H L L
15 L H H H
16 L H H L
Other objectives of the run were to test a new single fuel
injector and indirect cooling of the bed by means of
immersed water cooled tubes.
The configuration of the unit for Run 7 is described in
Section IV. Modifications from the Run 6 arrangements were
minor and consisted of:
a. Gasifier Distributor
The nozzle configuration of the distributor was restored
to that used in Run 3. Two heat exchanger tubes of
portal frame configuration were installed in the new
distributor together with a six-way central fuel
injector. Both the heat exchangers and the fuel nozzles
were rectractable and were installed in the retracted
position. These components were to be used towards the
end of Run 7.
- 36 -
-------
b. Regenerator Distributor
The original top-hat design of distributor was installed
in the regenerator but it was lowered lo cm (4 inches)
by means of the silicon carbide ring used in Run 6.
Provision was made for changing this-distributor during
the course of Run 7 should this prove to be necessary.
c. Regenerator Cyclone Drain
During Run 6 considerable amounts of fine bed material
were drained from the regenerator cyclone and lost
from the system. Provision was made in Run 7 for the
elutriation of this stream and the re-injection of the
coarser fraction into the gasifier bed.
d. Bed Transfer System
During Run 6 it was found expedient to rely on the
manual setting of the pulser in the regenerator to
gasifier transfer line for coarse temperature control,
the pulser on the gasifier to regenerator line being
used mainly to ensure that the R.H. cyclone drain
functioned properly. For Run 7 the temperature
controller was wired to the regenerator to gasifier
line and the gasifier to regenerator line was to be
operated manually.
e. Flue Gas Recycle Scrubber
During Run 6 there were several occasions when the
water drain from the flue gas recycle scrubber plugged
and water was entrained by the flue gas recycle stream.
A larger diameter drain was fitted to the demister for
Run 7.
TASK II
In the original programme of work, batch unit studies were
to determine the suitability of additional fuel-limestone
combinations for CAFB applications. However since Run 4
operations revealed a serious problem with BCR 1691 stone
which had not appeared in earlier batch unit tests, the
batch programme was revised to include an investigation of
dust forming tendencies under a variety of operating
conditions.
- 37 -
-------
In earlier batch work there had been a comparison of dust
losses between stones during gasification-regeneration
cycles. No such comparison had been made under fully
combusting conditions. In the normal batch unit test
procedure there had been little exposure of the solids to
combustion conditions in the absence of sulphur except
during calcination. Consequently the conditions
employed during Run 4 start up produced an entirely
unexpected result in that the BCR 1691 stone formed copious
quantities of a dust with a very sticky nature.
The batch unit test programme was revised to accomodate the
following objectives.
• Determine if continuous unit conditions which
produced large quantities of sticky dust could be
duplicated in batch units.
• Compare dust producing tendencies of Denbighshire
and BCR 1691 stones under different conditions.
• Provide a quantitative measurement of dust
production to be expected under start up and
operating conditions with Denbighshire, BCR 1691,
BCR 1359, and two additional stones to be provided
by New England Electric System (NEES).
• Measure sulphur absorption performance of BCR 1359
and the two NEES stones.
• Conduct tests of the feasibility of operating CAFB
with very heavy refinery streams, specifically,
vacuum pipe still bottoms.
In the event through activities pursued by Esso outside the
EPA programme a second heavy refinery stream was tested in
the batch units, and by agreement with Foster Wheeler Corp-
oration the results have been included in this report.
The procedure for operating the batch units are given in
Appendix M, and data are listed in Appendix N. Batch results
are discussed in Section VI.
- 38 -
-------
Batch test equipment is essentially the same as those used
in Phase I studies and is described in Section IV. The only
modification incorporated for those studies was the addition
of mechanical rappers to aid cyclone drainage when producing
the sticky fines characteristic of combusting conditions with
limestone BCR 1691.
TASK III
As part of this project, Esso Engineering, Florham Park,
New Jersey, USA, was requested to scope the engineering
effort which might be required to carry CAFB from its
present stage of development through the construction,
startup, and testing of a large scale demonstration unit.
A 100 MW scale unit was assumed as a basis. This scoping
study is summarised in Section VI. Detailed results have
been supplied to the Environmental Protection Agency in a
separate memorandum.
- 39 -
-------
SECTION VI
DISCUSSION OF RESULTS
TASK I - STUDIES IN CONTINUOUS GASIFIER
Four runs in Task I are discussed below in terms of equipment
performance and process performance. Prime attention is given
to Runs 6 and 7 since these have given the most self-consistent
and reliable data so far. Run 4 was prematurely terminated
by problems of dust formation, and data from Run 5 cannot yet
be made to balance on a self-consistent basis. Further
detailed examination of Run 5 data will be undertaken in Phase
III studies, which make provision for more extensive data
work-up and mathematical modelling based on results obtained
during the execution of this task.
Run 4
Equipment Performance is described in Appendix A. Major
problems were encountered during the start-up of the
continuous unit, in the following areas
(a) Blockage in solids transfer line
(b) Plugging in regenerator gas outlet system
(c) Oust emissions to boiler from gasifier
(d) Dust in flue gas recycle stream
(e) Dust emissions to atmosphere
(f) Regenerator Agglomerates
All of the problems were related to differences in the
characteristics of stone BCR 1691 frojn those of the Denbigh-
shire stone used in the continuous unit during Phase I
studies (Reference 1). The major differences are lower
fusion temperature, the cause of problems (a) and (f) above,
and production of a higher proportion of very fine dust in a
fluidised bed under fully combusting coditions, the cause
of problems (b) through (e). The dust produced from BCR
1691 is more difficult to retain in collection equipment
than that originating from Denbighshire stone. It also
clings to surfaces of pipes, cyclones, control valves etc,
and is difficult to dislodge without application of direct
mechanical force. It does not drain from hoppers, or even
vertical pipes, without continuous rapping.
- 40 -
-------
Despite these problems the unit was eventually started up
and gasification continued for a total of nine hours. At
this time the control valve downstream of the regenerator
cyclone plugged again and the run was terminated.
Examination of the gasifier after shutdown, coupled with the
results of batch tests on various limestones to assess dust
forming tendencies showed the need for several modifications
to the gasifier before attempting another run with a lime-
stone like BCR 1691. The modifications adopted are described
in Section IV. In retrospect it seems likely that if the
control valve had been cleaned one more time, and gasifying
conditions had then been maintained, a longer period of
gasification could have been achieved. However, it is also
probable control over gasifier conditions would have been
difficult, and achievement of steady lined out performance
unlikely.
Process Performance cannot be discussed in detail since the
9 hour period of gasification was far too short to achieve
lined out conditions. Table 5 summarises gasification
conditions and results obtained. Initially a high lime
replacement rate of 2.1 mole CaS was employed to build
gasifier bed level. A slight reduction to 1.7 mole CaS was
used during the final 4 hours. Sulphur removal efficiency
of nearly 98% at the higher rate declined to about 93% when
stone rate was reduced. However the gasification period was
too short to consider these results to represent lined out
conditions.
Table I Appendix A lists the distribution of particle sizes
in the solids from gasifier and regenerator beds and in
solids recovered from the boiler fire tube and regenerator
cyclone during gasification, and the elutriation effect of
the gasifier bed in removing particles smaller than the 355-
600 micron fraction is apparent. We would expect particles
smaller than about 500 microns to be entrained at Run 4 test
conditions. It is evident that little of the entrained
material was returned to the gasifier by the cyclone. The
presence of a wide spectrum of particle sizes in solids from
the boiler fire tube also indicates poor cyclone performance.
However the gasifier cyclone which drained back to the
regenerator evidently was operating as there was an
appreciable fraction of 15O-25O micron solids in the
regenerator bed.
- 41 -
-------
Table 5
Day Hour Temperature deg. C
Gasifier Regenerator
^
to
I
1
1
1
1
2
2
2
2
2
2030
2130
2230
2330
OO30
013O
0230
0330
0430
87O
882
872
870
875
881
875
872
872
.
1035
104O
1O8O
1100
1110
1015
1068
1O60
Superficial
Air Rate
ra/sec .
1.13
1.16
1.13
1.31
1,25
1.25
1.22
1.25
1.25
Fluidised Lime Replacement Air/Fuel
Bed Depth Mol CaO/Mol S % Stoich
cm.
49.5
50.8
55.6
59.2
59.9
6O.5
57.7
56.4
58.4
2.1
2.1
2.1
2.1
2.1
1.7
1.7
1.7
1.7
23.1
24. 0
23.6
24.3
24.1
24.1
23.7
24.0
24.2
Sulphur Remova
-
—
95.7
97.9
93.3
93.3
87.3
92.6
-------
The bulk density of the bed solids was higher than has been
observed in earlier studies. Batch unit tests with BCR 1691
had given settled bed densities of about O.83 g/cc compared
with values over 1.0 observed here. A change in density of
the fluidised bed had also been noted during the start up
period of Run 4. This density increased from about O.8 to
nearly 1.1 during the start up. It is possible that a
selective loss of lower density particles contributed to
this increase in bed density.
The chemical analyses of bed samples listed in Appendix A -
Table II show that silica content of the beds, and indeed
all solids samples/ increased over those of the raw lime-
stones . This change indicates that minerals other than
SiO2 were preferentially lost from the system, probably as
very small particles.
The difference between gasifier and regenerator bed sulphur
contents was 2.8% on stone indicating a good level of
regeneration. A very high fraction, 99%, of the regenerator
sulphur appeared as sulphate. This represents a considerably
higher degree of sulphide oxidation than achieved in earlier
runs and may indicate some oxidation of the sample during
its collection. The regenerator cyclone fines show a
slightly higher sulphur content than the gasifier bed sample.
They also show a high content of sulphide which indicates
that the fines passed through the regenerator without
undergoing much reaction.
Run 5
Equipment Performance is described fully in the run log and
post-run inspection in Appendix B.
Performance was greatly improved over that experienced in
previous runs, particularly that of Run 4. A number of the
new features operated well, but some continued to be trouble-
some throughout the run.
Stone Feeder -
The stone feed system which used a vibrator in a pressurised
shell to feed from a weighed hopper proved reliable through-
out the run. Stone feed rates were usually quite steady and
easily measured.
- 43 -
-------
Regenerator Drain Valve -
The gasifier bed level control system which used a pressure
switch in the gasifier to activate a drain valve in the
regenerator proved to be reliable and to give good control
of gasifier bed depth.
Regenerator Pressure Control -
No blockages were encountered in the regenerator off gas
line during Run 5. This line and its control system had
plugged continually during Run 4 start up. In Run 5 the
line remained clear and showed no sign of pressure build up.
The system used controlled introduction of excess air into
the outlet line downstream of the cyclone and avoided
restrictions in this line. It was not possible to operate
the system in automatic mode due to the large pressure
pulses introduced by the solids circulating system, but
manual control of the pneumatic valve position proved
satisfactory for control of the pressure difference between
regenerator and gasifier. Pressure difference was regulated
to within O.25 to O.5 kPa (one or two inches water gauge).
Normally the regenerator pressure was adjusted to be O.75 to
1.25 kPa (3 to 5 in w.g.) below gasifier gas space pressure
although higher differences were sometimes used.
Cleanliness of the regenerator gas line was also aided by
continuous use of a pneumatic rapper on the regenerator gas
cyclone. This rapper ensured drainage of solids from the
cyclone walls. Also, the conditions that produced the very
sticky fines, kerosene combustion in a bed of BCR 1691 stone,
were avoided as much as possible.
Flue Gas Recycle Scrubber -
The venturi scrubber on the flue gas recycle stream removed
a great deal of lime fines from the gas, but was not
completely effective. Some particles passed the scrubber,
and some fouling of the recycle gas line, control valve,
and gasifier distributor was encountered. The rate of
gasifier distributor pressure rise in Run 5 was much less
than in prior runs. In the initial stages of Run 5 there
was frequent plugging of the inlet of the venturi throat
itself with lime deposits. Increasing the gas flow through
the venturi to the maximum rate available (estimated at
340 mj/hr) (2OO CFM) by using maximum recirculation
eliminated plugging at this point.
- 44 -
-------
The drain line from the water separator occasionally blocked
and required cleaning.
On at least three occasions blockage of this discharge caused
water carryover to the gasifier plenum itself with a
consequent sharp decrease in gasifier temperature.
Regenerator Over Temperature Protection -
The new regenerator emergency quench system dilutes the
inlet air with nitrogen when regenerator temperature reaches
the set point of 11OO deg.C. This system proved to be quite
valuable and avoided excess temperature several times when
malfunction of the solids circulation system reduced lime
flow rate through the regenerator. In only one case did
regenerator temperature seriously exceed 11OO deg. C, and
that was due to emptying of the quench N2 supply bottle before
normal conditions were restored. This quench system is
believed to be responsible for avoiding regenerator blockages
by agglomerated solids which occurred in previous runs.
Boiler Pilot Flame -
The new boiler pilot burner and its gas and air system were
quite effective in.providing a stable and reliable pilot.
No difficulty was met in lighting the pilot over a wide
range of conditions nor in keeping it lit.
Stack Top Washer -
The water spray scrubber installed to prevent discharge of
dust to the atmosphere was operated during part of the run
when it appeared that some dust was passing the external
flue cyclone.
When operated the scrubber appeared to be effective in
avoiding dust emissions. Because of the diffuse upward
discharge of gas from the system, it was not possible to
obtain a quantitative measure of the actual dust content.
Corrosion of the water recycle piping in this scrubber system
was severe because of SO2 from the regenerator which was
remixed with the boiler gas in the stack.
Cyclone Fines Return System -
The gasifier cyclone fines return system operated well
during much of the run in spite of several deficiencies.
- 45 -
-------
Operation was trouble-free for most of the first 1O9 hours of
gasification and for the final 127 hours. During other
periods there were a number of upsets. Two problems were
encountered in the first period:-
(1) Dust worked its way back to the pneumatic control
system through a pressure measurement line and caused
stoppage. This problem did not recur after installation
of a fine filter and additional N2 bleed in the pressure
line.
(2) Residual pressure remained in the conical dust receiver
after a transfer of solids when the butterfly valve to
the cyclone drain opened to begin refilling, this
pressure caused a surge of gas back up the cyclone leg
and upset the cyclone operation. The result was a burst
of fines into the boiler after each transfer operation.
These puffs were evident in the peaks observed in
boiler S02 emission. This difficulty was removed by
installation of a delay device which allowed pressure
to discharge down stream from the conical receiver
before the valve to the cyclone could open.
Most of the problems met during the mid run period were
caused by chips, flakes, and chunks which found their way
into the cyclones and transfer system after each temporary
shutdown and decoking operation. It was necessary to
disconnect vessels and lines on several occasions to remove
these flakes and chunks. In other cases these solids
prevented good operation of the butterfly valves. When the
butterfly valves failed to seat properly before a transfer,
N2 gas again blew back through the cyclone and sent dust to
the boiler.
Installation of a chunk trap in the elutriator drain during
the run improved operation a great deal. Installation of
additional chunk traps in the conical vessels were planned
as a further aid.
Efficiency of the cyclones themselves deteriorated during
the run. In the initial period efficiency was fairly high,
and only a small amount of very fine solids entered the
boiler. In later stages of the run the efficiency
deteriorated, and a considerable quantity of quite coarse
solids entered the boiler.
- 46 -
-------
Inspection of the cyclones at the end of the run revealed
them to be nearly completely choked with a mixed deposit of
lime and carbon in the annular space between walls and gas
outlet tube. The steel liners which had been installed
before Run 5 were severely burned and distorted. The silicon
carbide gas outlet tubes were strong, smooth, and intact.
It is evident that demonstration of an effective way to
maintain cyclone efficiency must remain an important problem
area of this work.
In view of performance of the process, it is clear now that
recycle of cyclones fines to the gasifier without a means to
achieve their regeneration is not desirable. The fines, with
their large surface area, pick up a considerable load of
sulphur and make a number of cycles through the gasifier and
cyclones without entering the regenerator. If any of these
fines escape the cyclone, they enter the boiler and cause
loss of sulphur removal efficiency. A means of providing
preferential regeneration of the fines is a desirable
process feature.
Regenerator Operation -
Dufluidisation of the regenerator bed occurred twice during
gasification in Run 5 and once under combustion conditions.
The cause of this behaviour has not been established, but
gas by-passing in some manner is suspected. The effects of
such by-passing would be aggravated by lack of fines in the
regenerator solids which would increase minimum fluidisation
velocity. Two of the ways in which by-passing could occur
are leakage of gas through the solids circulation passages
and leakage through cracks. It is possible for air to enter
a crack in the refractory near the bottom of the bed, travel
upward through the crack, and return to the vessel higher up.
A small crack was observed in the regenerator wall and
patched during the run, but it did not appear large enough
to account for the troubles observed.
The fact that the tendency to defluidise became more severe
with time during the gasification periods involved suggests
that it may have been related to another time dependent
factor such as the increase in gas space pressure which took
place as gasifier outlet passages gradually fouled. Leakage
of air back into the gasifier-to-regenerator solids transfer
line and up the unused portion of the cyclone fines return
leg could follow such a course. Such leakage would have to
pass into the cyclone past the steel sleeve insert which had
been dropped into the cyclone leg as a seal. However,
- 47 -
-------
distortion of the steel sleeve by heat following gasifier
decoking is a distinct possibility. On the other hand,
such a loss of air near the regenerator bottom does not
accord with the apparent low SO2 concentration measured
in the regenerator gas. Indeed, sulphur material balance
considerations imply that the gas flow through the
regenerator was higher than that supplied by the regenerator
air blower. It is probable that further tests will be
needed to establish the cause of this unusual regenerator
behaviour.
Boiler deposits -
Boiler deposits found within the boiler were of two types:
(1) Loose accumulations of dust or coarser particles in
the soot trap areas at the boiler ends.
(2) Agglomerated deposits formed from very fine particles
which build up at the inlets to the first pass of
small fire tubes.
The loose accumulations of particles do not appear to present
a long term problem. They would be subject to easy removal
by normal soot blowing techniques.
The agglomerated fines represent a potential problem area
which requires additional study to define its severity in
large scale equipment. Certainly it is an inconvenience in
our pilot plant equipment. However it must be stressed
that the fire tube boiler used for our pilot plant tests is
in no way typical of a water tube power generation boiler and
the problems we have experienced may be typical only of the
particular boiler we are using. From the point of view of
deposit buildup the pilot plant boiler is far from ideal.
Deposits are very local in nature; being found only at the
inlets to the first set of water cooled fire tubes, where
the gases change direction by 180 deg. in a downward direction.
They did not form after the first few cm of tube length nor
were they found to any significant degree on a test probe
inserted radially into the gas stream at the end of the main
fire tube as a simulation of a superheater tube in a water
tube boiler. These deposits evidently form from fine particles
which are in a sticky state following their passage through
the flame. The growth of the deposits was faster during the
first 109 hours of Run 5 gasification than during the final
127 hours. Whether this difference was due to the presence
- 48 -
-------
of BCR 1691 stone in the first period or to the eroding
effect of a higher concentration of coarse particles during
the final period remains to be established. It is possible
that deliberate injection of a small amount of coarse stone
into the boiler could prevent deposit formation. No
deposits were found at the tube inlets during the 111 hours
of gasification in Run 2 during which a high concentration
of solids passed through the boiler.
Process Performance is summarised in Table 6 which lists
values of operating conditions and results for the various
test periods of Run 5. Each value is the average for four
hours operation. In most test periods a set of solids
samples was collected for analysis.
Sulphur Removal -
The degree of sulphur removal in the pilot plant is calculated
from the measured SO2 and C02 contents of the boiler flue gas
compared with sulphur and carbon contents of the boiler fuel.
The carbon content of the pilot burner propane is considered
in this calculation, as is the CC>2 released by calcination
of limestone makeup.
During Run 5, sulphur removal efficiency (SRE) varied from
6O to 99%. Appendix figure B.15 shows the hourly levels of
SRE along with other important variables. Figure 8 shows the
effect of lime replacement rate on SRE for individual test
periods. It is apparent that lime replacement has an effect
on SRE.
The effect of other variables are less clearly defined. In
particular, increasing gasifier bed depth did not produce
the expected improvement in SRE over results obtained in
earlier runs with shallower beds.
It appeared in this run that the beneficial effect of
increased bed depth was offset by increasing fines loss rate.
The loss of fines hurts sulphur removal efficiency in two
ways. Firstly it removes the high surface area fraction of
the lime which has greatest potential for sulphur pickup, and
secondly, when sulphur laden fines enter the boiler they
partly regenerate to contribute SO2 to the flue gas.
The effect of bed depth was also obscured by the fact that
deterioration in cyclone performance made it difficult to
operate with deep beds at very low lime replacement rates.
- 49 -
-------
Table 6
Day Time
2.213O
3.0530
3.1530
3.2130
5.103O
6.0730
12.0830
12.153O
12.193O
I 13.0330
m 13.063O
O 17.1230
I 17.1730
21.0930
21.1830
22.073O
22.1830
24.0730
25.0530
25.1530
26.0530
26.1130
26.1830
Temperature deg. C
Gasifier Regenerator
883
886
8*4
894
852
856
877
870
871
8(8
876
863
861
9O3
889
878
873
862
878
875
880
866
872
1047
1063
1O61
1O66
1053
1055
1050
1036
1O55
1031
1024
10S2
1047
1062
1065
1070
1069
1057
1060
1O60
1060
1O60
1O60
Lime Replacement
mol Ca/mol S
.62
.64
.48
.62
1.76
1.19
.81
1.14
1.07
1.01
.87
.90
1.55
1.16
1.40
.96
1.03
2.01
1.48
1.36
1.04
1.32
1.41
Gasifier Depth
cm water
48.8
52.3
54.6
45.7
45.7
44.7
53.6
56.6
55.4
46.7
46.2
63.5
64.3
55.9
57.7
58.4
61
62.5
64.3
65
63.5
63.2
64.5
Fuel Rate
kg/hr
iai
180
179
183
181
174
181
180
173
178
177
181
182
213
213
187
186
186
134
183
184
186
186
Sulphur Removal
%
77.5
72.8
74.8
60.2
95. 0
94.5
79.1
84.6
85.5
83.4
87.2
84.0
76.9
93.3
89.1
91.2
85.0
99.3
93.7
90.3
90.8
92.0
86.1
Regenerator SO.
Cone. Volt % of S Fed
4.1
4.4
3.0
2.6
5.1
4.6
4.1
3.7
4.1
4.0
3.9
4.7
3.8
3.8
4.4
4-.0
3.7
3.7
3.6
3.6.
3.i
3.4
3.4
32.7
43.3
28. 0
23.1
44.7
36.9
48.3
43.9
46.5
47.0
48.5
46.1
38.4
32.8
35.8
38.4
34.6
34.4
35.4
34.9
32.3
34.5
33.3
Stone
Denbighshire
it
m
H
BCR 1691
It
H
H
If
H
H
H
II
Denbighshire
N
H
N
"
•
•
it
H
M
-------
100
1
SYMBOL RUN
3
•
A 4
V 5
O 5
I
LIMESTONE -H
DENBIGHSHIRE
BCR 1691
BCR 1691
DENBIGHSHIRE
I 2 3
LIME RELACEMENT RATE, Mot Co/Mol S
Figure 8 CAFB Pilot Plant Sulphur Removal Efficiency
-------
Results are summarised in Table 7. The water scrubber on
the stack top was able to catch the worst of the material
which escaped the cyclone, but since the quantity recovered
by the scrubber was not measured, it is included with the
stack losses.
Table 7
Summary of Solids Loss - Run 5
Time Limestone
Day. Hour Feed
3.153O Denbighshire
3.2030 "
5.103O BCR 1691
6.0730 " "
12.1730
13.0330
17.1130 "
17.1730
21.183O Denbighshire
22.0630 "
22.1730
25.0530 "
25.1430
26.0430
26.1730 "
Make-up
Rate
(kg/hr)
3.3
3.3
27.2
12.3
11.8
11.8
9.7
19.5
1O.O
10.0
7.7
11.3
11.3
7.9
7.9
Gasifier Fluid Loss Rate
Bed Depth (kg/hr)
(cm) Gasifier Stack
69.9
57.2
76.2
67.8
80.0
70.1
90.7
94.2
78.0
72.9
76.2
90.7
92.5
90.7
99.6
0
2.4
13.6
8.3
14.1
9.8
8.3
15.1
8.6
7.8
6.0
7.4
7.7
6.0
5.4
O
1.2
10.6
6.9
10.1
6.7
4.4
11.7
5.4
4.7
2.9
0.1
2.0
0.5
O
Bed
Si02/
CaO
Ratio
O.OO6
O.OO6
0.203
0.236
0.224
O.217
0.199
0.185
O.O53
0.053
0.038
0.023
0.016
-
-
- 52 -
-------
The test at 9OO deg. C gasifier temperature on day 21
produced sulphur removal efficiency over 9O% and demonstrated
the feasibility of operating at this temperature with a low
air/fuel ratio. The fuel rate in this test was 213 kg/hr (469
pounds per hour), the highest yet used in the pilot plant.
Pressure drop in the boiler prevented increasing fuel rate
still further to test completely adiabatic gasifier operation
without flue gas recycle.
Metals Retention -
Comparing the metals content of spent lime with the metals
content of fresh limestone and fuel oil, it is possible to
estimate the degree of metal retention by the solids. Figs.
9, 10 and 11 compare the retained weights of vanadium,
sodium, and nickel with quantities of these metals fed during
various operating periods of the pilot plant.
Vanadium retention is essentially complete, in agreement
with predictions based on batch unit tests. Sodium retention
was 36%, somewhat higher than the 2O% level obtained in
batch tests. Nickel retention, which was not studied before,
averaged 75%.
There appeared to be no significant difference between metals
pick up efficiencies with Denbighshire and BCR 1691 stones.
However because of differences in stone loss rates, there is
a difference in absolute metal retention levels in the unit.
With Denbighshire stone there was practically no lime loss
from the system. That lime which escaped the gasifier
cyclones was caught either in the boiler or by the external
flue gas cyclones. However with BCR 1691, losses amounted
to as high as 40% of the lime replacement rate and of course
any associated metals were lost as well. While not affecting
the ability of the CAFB gasifier to remove vanadium as a
source of high temperature corrosion of boiler superheater
tubes, the loss of metals on lime particles would be a
pollution factor which could be reduced even further by
increasing the efficiency of the particulate removal portion
of the system.
Solids Losses -
To obtain a more comprehensive picture of solids losses
during Run 5, both the amount of material emitted by the
gasifier into boiler and the amount escaping the external
cyclone into the stack have been computed.
- 53 -
-------
SYMBOL GASIFICATION
PERIOD
V I
X |
• 3
O 4
+ 5
A e
TIME
PERIOD
I.I73O-4.OOOO
4.0000- e.0*30
II.I23O - I34C3O
20-H3O-2MWO
23.0T3O-26-W30
LIMESTONE
FEED
OENWGHSHIftC
BCR 1991
•CN 1691
BCR l«9i
OENBI8HSHIRE
DENBIGHSHIRE
TUEL VANADIUM CONTENT 3OOppm
I
Ol
in
oc
> 3
•»
I
5.00O
10,000 15,000
FUEL CONSUMED (Ktt
2OOOO
Figure 9 Vanadium Retention (Run 5)
-------
SYMBOL GASIFICATION
PERIOD
I
I
3
4
5
6
TIME
PERIOD
I.I73O -4.0000
4.0000- 6.0*30
II I23O - I3.O63O
I6.0630-I7.ai30
2O. I83O - 22.1930
23.0730-26-1830
LIMESTONE
FEED
DENBIGHSHIRE
BCR 1691
8CR 1691
BCR 1691
DENBIGHSHIRE
DENBIGHSHIRE
05
FUEL SODIUM CONTENT 37ppm
O
UJ
UJ
te.
01
en
BO-25
1
I
5000
10,000 ISjOOO
FUEL CONSUMED (Kg)
20,000
Figure 1O Sodium Retention (Run 5)
-------
O-75
gO-5
UJ
oc
I
en
0-35
SYMBOL GASIFICATION
PERIOD
I.I73O - 4.0000
4 OOOO- 6.0830
11.1230 - 13.0630
I6-0630-17.2130
20-1830-22.1930
23.0730-26-1830
FUEL NICKEL CONTENT 41 ppm
I
LIMESTONE
FEED
DENBIGHSHIRE
8CH 1691
BCR 1691
BCR 1691
DENBIGHSHIRE
DENBIGHSHIRE
_L
5,000
10,000 I5POO
FUEL CONSUMED (Kg)
20,000
Figure 11 Nickel Retention (Run 5)
-------
Taking gasifier losses first, it is apparent that these
varied considerably during the run. Previously, in batch
units it had been found that gasifier loss rate was dependant
on make-up rate and bed depth (Reference 1). In Run 5, however,
the situation was more complicated since cyclone performance
was known to have deteriorated sometime during the run. This
was evident from the after-run inspection which showed the
cyclones to be in poor condition. Statistical analysis of
gasifier loss rates showed an inconsistancy between the first
and second data points (3.1530 and 3.2030). Also all later
variations for both stones could be explained by changes in
bed depth and make-up rate in a single correlation.
From this analysis, the following was deduced. Firstly,
cyclone performance deteriorated between the 3.1530 and
3.2O3O data points and did not alter appreciably thereafter.
The reason for the deterioration is not as yet clear.
Secondly, gasifier loss rates at constant cyclone performance
were shown to depend on make-up rate and bed depth. Whilst
the effect of make-up rate was similar to that observed in
batch units, bed depth appeared to be less significant.
Thirdly, gasifier loss rate was independent of limestone
type in this instance. This would not always be the case.
Here, it would appear that the cut-off point for the reduced
performance cyclones and the attrition patterns for the two
limestones is combined to cause this phenomenon.
For stack losses, a very different picture emerged when
these results were examined in detail. The two limestones
behaved differently. Under all conditions examined, stack
losses were small when the bed was composed mainly of
Denbighshire limestone. With predominantly BCR 1691 (5.1O3O
to 17.1730), however, they were appreciable. They were also
higher when of the order of 2O% of the bed as estimated from
Si02/CaO ratios was BCR 1691 (21.1830 to 22.0630).
Statistical analysis also showed that stack losses from a
BCR 1691 bed correlated with make-up rate and bed depth.
Since the performance of the stack cyclone did not change
during the run, these variations in stack losses can only be
explained if it is accepted that BCR 1691 produces a fraction
of material of much smaller particle size than Denbighshire.
This has been indicated from Run 4 and batch test data.
Since the stack cylcone was designed to have the same
efficiency as the gasifier cyclones, the results from Run 5
indicate that a gasifier following the same principles for
- 57 -
-------
solids handling as the pilot plant and with gasifier cyclones
fully operational would give negligible gasifier losses with
a limestone of Denbighshire type and gasifier losses of the
order of stack losses with a limestone of BCR 1691 type.
Bed Homogeneity -
uoth Denbighshire and BCR 1691 limestones were tested in
Run 5. A measure of bed homogeneity with respect to lime-
stone type was obtained by analysing bed samples for silica
and calcium oxide and comparing the ratio of these two
compounds. The silica to calcium oxide ratio for the high
purity Denbighshire stone is much lower at O.OO6 than BCR
1691 at 0.28. Results are summarised in Table 8.
For the first two data times, the system was completely
homogeneous since only Denbighshire stone had been added.
During the subsequent BCR 1691 test period, the bed always
had a SiO2/CaO ratio below that of the raw stone. Also no
persistent increase in the ratio was observed.
During the final Denbighshire test period, a reduction in
SiO2/CaO ratio took place and the ratio of the raw Denbigh-
shire stone was approached. Material from the stack cyclone
gave similar results to that from the regenerator cyclone
throughout. During the BCR 1691 test period, the Si02/CaO
ratio in these fines was generally higher than that for the
raw stone.
The significance of the Si/Ca ratios during the BCR 1691
tests is somewhat obscured by the fraction of Denbighshire
stone which remained in the bed following changeover to BCR
1691.
We believe that the low Si02/CaO ratios in the bed during
BCR 1691 tests was due to residual Denbighshire stone. The
absence of any increase in ratio over the period can be
attributed to the addition of Denbighshire stone during burn-
out and maintenance periods between 6.O73O and 12.163O and
also 13.O6OO and 17.113O.
We discount the possibility of a preferential loss of silica
from the beds being the cause of the low results even though
higher SiC>2/CaO ratios were observed in cyclone fines.
The reason being that beds composed only of BCR 1691 in batch
tests and Run 4 showed the opposite effect in that silica was
concentrated in the bed. In those instances the fines which
- 58 -
-------
Table 8
Silica/Calcium Oxide Ratios (Run 5)
Time
Day Hour
3.1530
3.2030
5.1045
6.O730
' 12.1630
*> 12.18OO
1 13.0400
13.0600
17.1130
17.1800
21.O7OO
21.1800
22.0715
22.1745-
25.0530.
25.1430
Limestone
Feed
Denbighshire
n
BCR 1691
n
11
n
n
n
n
Denbighshire
H
H
If
n
ii
Gasifier Bed
Si02/CaO
O.OO6
O.OO6
O.2O3
0.236
0.228
0.224
0.217
0.242
0.199
0.185
O.O56
O.O53
0.053
O.O38
0.023
0.016
Regenerator
Si02/CaO
O.OO6
0.006
O.215
0.218
0.258
0.225
-
0.225
0.106
0.214
-
-
-
-
0.020
-
Stack Cyclone
Si02/CaO
O.OO6
0.006
0.283
0.261
0.301
0.316
0.313
0.312
0.303
0.301
-
O.015
O.OO7
O.01O
O.OO6
_
Regenerator Cyclone
SiOj/CaO
O.OO6
O.OO6
O. 3O5
O.3OO
0.283
0.286
-
0.304
O.266
0.273
O.OO9
-
-
-
0.006
—
-------
were trapped also showed a higher ratio than the raw stone
indicating that the material lost completely from the system
was rich in calcium. Assuming the same to have happened here
with the BCR 1691 fraction of the bed, then the higher SiO2/CaO
ratio in the fines can be explained by BCR 1691 being lost
preferentially.
After the final change to Denbighshire feed, the SiC>2/CaO
ratios indicated that some BCR 1691 was present in the bed
to the end of Run 5, albeit in ever decreasing amounts.
Particle size of solids -
Tiie particle size distribution of solids in the reactor beds
depends on size of the feed, particle attrition, and
effectiveness of the cyclones in returning fines. Sieve
analysis of a number of gasifier and regenerator samples are
presented in Appendix B. Histograms of the average stone
feed and two sets of gasifier and regenerator bed samples
are given in Figure 12.
The two sets of bed samples illustrated represent extremes
of the samples taken. Performance of the fines return system
was poor at 13.04OO, and fines were being lost from the unit.
The cyclones and fines return system were operating relatively
well at 21.16OO as shown by the larger fraction of small
particles.
These figures show that the fraction of particles in the
250 to 14OO micron size range was increased in the unit at
the expense of both larger and smaller sizes. The fraction
below 25O microns in the gasifier was lost altogether while
the quantity of material above 14OO microns was reduced.
Poor performance of the fines return system, as at 13.0400
causes significant loss of particles as large as the 6OO-85O
micron range. Regenerator and gasifier beds were quite
similar in size distribution with the regenerator showing a
slightly higher fraction of fines.
Figure 13 shows the variation, during the run, of the fraction
of bed in the size range below 600 microns.
This figure indicates a rapid deterioration of fines return
effectiveness during the early part of the run. It indicates
that fines return was restored during decoking before day 21
startup but again declined toward the end of run.
- 60 -
-------
100
2
50
T
T
GASIFIER 21,1600 — -~^
' REGENERATOR 21,1800 - - 775
•.
x|o
IOOA3 fJ '
GASIFIER 13,0900 —
. REGENERATOR 13,0600 1132
2 50
UJ
€/)
- 100/0
AVERAGE OF LIMESTONE FEED
Dov • 955
I
I
1000 200O
PARTICLE SIZE, MICRONS
3000
Figure 12 Size Distribution of Fluid Beds
(Run 5)
- 61 -
-------
35 r
30
25
o
O
O
z
<
I
- GASIFIER O
REGENERATOR X
20
2 15
en
3« 10
I h—4 H
I
O
O
Ox
I—- 1
10
15
RUN DAY
20 25
30
Figure 13 Gasifier and Regenerator Fines
below 60O microns (Run 5)
- 62 -
-------
A similar pattern is shown in Figure 14 where average particle
size of the bed is plotted against run time. The particle
size here is calculated from sieve analysis, using the
relationship:
dAV = W
W/d
which gives a surface area mean particle size.
Nitrogen Oxides -
The concentrations of nitrogen oxides measured in the boiler
flue gas during Run 5 are compared in Table 9 with values
measured in previous tests. All samples were taken from the
boiler flue gas by means of gas sample bags and analysed off
line in the laboratory. A chemiluminescence method was used
for Run 5 samples.
The ASTM D1608 phenol-disulphonic acid method was used for
the other samples. Laboratory cross checks have indicated
that the two methods are in agreement.
Run 5 results agree generally with earlier gasification
test results. All of the gasification results have lower
NOx concentrations than the tests with the oil burner. This
improvement during CAFB gasification is probably due to a
combination of the effects of two stage combustion and the use
of flue gas recycle. It is possible that nitrogen compounds
in the fuel are converted to a harmless form during
gasification, and that flue gas recycle reduces maximum
flame temperature which reduces equilibrium NOx concentration.
Even with the original oil burner operation the
concentrations were low when compared with concentrations in
the flue gas of large power station boilers. This
difference in overall level is believed to be caused by the
close proximity of the flame to the large water cooled
surface in the fire tube boiler used in the pilot plant.
Therefore, although the reduction in NOx level caused by
CAFB gasification is believed to be realistic, the absolute
low level achieved probably would not be reached in large
power generation boilers where flame temperatures are much
higher.
- 63 -
-------
I4OO
z
o
-------
Table 9
Operating Mode
Oil Burnerrlow fire
M H
Oil Burner-High fire
It H
Gasification Run 1
Run 3
in.
Run 5
Nitrogen
Sample Date-Time
May 1971
H n
It M
It «
August 1971
• M
n n
• N
1 Dec 1971
3 Dec 1971
It H
H H
« M
6 Dec 1971
• H
H N
• H
9 Feb 1973
17 Feb 1973
22 Feb 1973
15:55
16:00
16:05
09:50
O9:55
10:05
1O:1O
13:45
13:50
14:OO
14:O5
15:00
OO.-OO
16 : 1O
Oxides in CAFB Boiler Flue Gas
Method
ASTM D16O8
M
If
«
ff
N
H
n
n
n
M
M
M
H
M
•
H
H
(a)
Chemi luminescence 101 ,
n
n
NO^ cm3/m3
256
249
280
266
179
155
172
2OO
126
120
130
163
173
169
163
237
186
181
166
103, 110
18O
185
Flue Gas O^Vol% Oil Rate kg/hr
2.9 - 3
2.4 - 2.3
1.0
3.0
3.7
2.9
164
It
n
175
n
ii
n
145
179
183
181
(a)
Thermo Electron Corporation NO Analyser Model 1O (a)
X
-------
Thermal Behaviour -
Most of the heat released by partial combustion of fuel in
the gasifier is retained as sensible heat in the gas going
to the burner. The heat release in the gasifier has been
estimated from thermal equations for the masses and heat
contents of the various streams entering and leaving the
gasifier. Table 10 lists results for Run 5 test conditions.
The equations used are explained in Appendix I,
Heat losses from the pilot plant gasifier bed, based on
reasonable values of thermal conductivity and heat transfer
coefficients, amount to about 1% of the heat released in the
gasifier. Depending on lime replacement rate, about 2 to 4%
of the heat released goes to calcine stone and raise the lime
to gasifier temperature. At the air/fuel ratio employed,
which did not deviate much from 20% of stoichiometric, the
heat release per pound of fuel was estimated to be
approximately 7211 kJ/kg (310O BTU/lb) corresponding to
360,530 kJ/kmol (155,OOO BTU/mole) of oxygen.
Figure 15 shows the observed variation of fuel heat release
with air/fuel ratio, and compares the measured values with
a line calculated for a release of 360,530 kJ/kmol (155,OOO
BTU/mole) of oxygen. Values from all the pilot plant runs
to date fall along this line. This value of 360,530 kJ/kmol
02 agrees well with heat release calculated from the fraction
of carbon and hydrogen oxidised and the CO/CO2 ratio formed
in the gasifier. Details of this calculation also appear in
Appendix I.
Product Gas Composition -
Four samples of the gasifier product vapour were collected
during the run and analysed by gas chromotograph. This
analysis gives dry gas composition on a water and liquid
hydrocarbon free basis. Results are listed in Table 11.
- 66 -
-------
Table 1O
Heat Release in CAFB Gasifier
Run 5
a\
Air/Fuel
Run.Tine % of
Stoichiometric
2.2130
3.0530
3.1530
3.2130
5.1030
(.0730
12.1530
12.1930
13.O33O
12.0830
17.1230
17.1730
21.0930
21.1830
22.0730
22.183O
24.0730
25.0530
25.1530
26.0530
26.1830
13.063O
26.113O
19.8
20.4
20.6
2O. 3
21.3
20.4
20.6
20.6
20.7
20.6
21.3
21.9
19.7
19.0
19.6
19.8
19.2
19.2
19.1
18.9
18.7
20.8
18.1
Heat Lost
% of
Heat Release
.73
.78
.71
.66
.83
.77
.94
.97
.80
.86
1.09
1.04
.80
.82
.86
.88
.97
1.06
1.07
1.O7
1.16
.80
1.10
Calcination arid
Stone Heating
% of
Heat Release
49
58
16
49
4.42
02
06
2.93
2.60
2.15
2.38
4.03
3.05
3.67
2.43
2.58
4.92
3.66
3.4O
2.63
3.57
2.22
3.37
Heat From
Regenerator
% of
Heat Release
5.
4.
4.
4.
4.10
5.33
.14
.64
.88
.31
5.66
7.57
5.71
5.39
5.31
5.56
4,
4,
5.
5.
5.
5,
5.
.96
.07
.02
,14
,30
.89
,62
6.O6
5.74
5.77
5.98
Gasifier
Beat
Release
kJ
369
360
369
378
384
363
36O
349
369
369
366
375
407
410
372
369
378
372
366
366
366
369
363
Oil
Heat
Release
kJ/kg oil
7378
7215
7436
7432
7620
7529
7222
7036
7478
7362
7276
7411
6901
6925
7132
7159
7315
7280
7173
709O
7085
7501
7034
O2 Heat
Release
kJ/kmol
3709O2
352294
359281
363OOO
355338
367334
347809
339075
359O55
354394
338761
335653
348456
362649
362491
358509
378980
376956
373311
372893
375721
357925
386546
-------
7500
UJ
2
o»
7000
UJ
CO
!j 6500
UJ
QC
h-
LU
I
o:
y 6000
u.
CO
SYMBOL
x
A
V
LINE CORRESPONDS WITH
360,530 KJ/K Mol 0,
1
V
RUN
3 EARLY
3 LATE
4
5
I
16 18 20 22 24
AIR/FUEL RATIO, % OF STOICHIOMETRIC
26
Figure 15 Heat Release of Air/Fuel Ratio
During Gasification
- 68 -
-------
Table 11
Product Gas Composition
Run 5
Jample Time 22.1030 22.1745 26.O4OO 26.180O
Composition, Vol %
(Air Free Basis)
N2
C02
CO
H2
CH4
C2H4
C3H6
A material balance calculation on the product gas composition
and unit feed rates permits an estimate of the quantity and
composition of that portion of the product vapour which is
missed by the gas chromatograph because of condensation in
lines or in the sample container.
In this calculation nitrogen and oxygen balance are forced
to 10O% and the amount of hydrogen and carbon not accounted
for is assumed to make up the liquid fraction. The flue gas
recycle stream was assumed to contain the same H2O/CO2 ratio
as the boiler products of combustion. Table 12 summarises
results of this calculation. Details appear in Appendix
Table L-l.
The results are fairly consistent in indicating the fractions
of carbon and hydrogen oxidised and the quantity of carbon
which goes either to coke or heavy hydrocarbons. The results
on hydrogen disappearance show greater variability however.
- 69 -
61.7
10.82
8.36
6.86
6.75
5.36
-
62.5
10.89
7.52
7.75
6.29
4.83
.11
63.4
10.88
9.36
6.42
6.09
3.81
^
64.7
10.17
8.97
5.80
6.02
4.38
_
-------
Tabla 12
Summary cf Gasifier Component Distributions
(Calculated from Flow* and Product Gas Composition)
Sample Time
22.1030
22.1745
26.0400
26.1800
Oxygen In, t of Total
With Air
With Flue Gas Component*
From Solids Reactions
67.7
23.7
8.6
66.4
23.6
7.9
66.9
23.0
10.0
66.4
23.6
1O.O
Oxygen Out, % of Total
As Sulphate on lime
As Carbon Oxides
As H20 (by Difference)
1.7
83.7
14.5
1.6
61.6
16.7
1.3
84.4
14.4
1.5
77.9
20.5
Hydrogen In, t of Total
In Oil Feed
In Flue Gas H20
94.1
5.9
94.2
5.8
94.3
5.7
94.3
5.7
Hydrogen Out, t of Total
As Dry Gas Components 82.2
As H20 13.8
As Heavy Components (By Difference) 4.0
79.6
15.8
4.6
67.1
13.6
19.3
49.8
18.7
31.4
Carbon To Gasifier, % of Total
In Oil Feed :
In Flue Gas, C oxiles
In Stone
93.2
5.8
1.0
93.5
5.6
0.9
93.5
5.5
1.0
93.1
5.5
1.3
Carbon From Gasifler, t of Total
As Oxides from Gasifier 4O.6
As C02 from Regenerator 1.0
Aa Hydrocarbon in Dry Gas 37.O
As heavy Components (By Difference) 21.5
38.7
0.4
33.5
27.4
41.5
O.2
28.1
30.3
37.1
o. :i
28.6
34.0
C oxidised, % of Feed 35.8
H oxidesed, % of Feed 14.6
C in Heavy Components, % of Feed 23.9
H In Heavy Components, % of Peed 4.3
34.0
15.8
30.0
4.8
37.0
14.4
33.1
20.4
31.9
19.9
37.4
33.3
C0/C02 in fresh oxides 1.1O2
H/C in Heavy Component* .29
Air/Fuel Ratio, % of Stoichiometrlc 19.5
.97
.26
19.8
•1.22
.99
19.3
1.36
1.43
18.3
- 70 -
-------
This variability is probably due to the method of calculation
which depends on finding small differences between relatively
large numbers.
In particular, the hydrogen/carbon ratios of .29 and .26
calculated for the heavy components on day 22 appear to be
unreasonably low. It is unlikely that the true H/C ratios
could be much less than 1.0. These results show the
desirability of obtaining accurate samples of the total
gasifier product, including light and heavy components.
However, collection of such a sample is quite difficult in
practice, and will require development of a suitable quench
and recycle system to collect the liquid fraction without
plugging.
Regenerator -
Performance of the regenerator during Run 5 appeared to be
less satisfactory than in earlier tests and was somewhat
inconsistent. It was disappointing in that sulphur
concentration in the off gas and selectivity of calcium
sulphide oxidation to calcium oxide plus SO2 appeared to be
much lower than the levels which earlier runs had shown to
be possible. Results were inconsistent in that the apparent
sulphur production rate of the regenerator could account for
only about half the sulphur being absorbed in the gasifier.
Furthermore, S02 release based on gas analysis did not agree
with SC>2 based on solids analysis. Obviously this matter
requires additional study to locate the cause of the
discrepancy.
The run data shown in Appendix Figure B-16 are the gas
analysis based values of SO2 concentration and selectivity.
Table 13 compares regenerator sulphur emission figures based
on gas analysis with values calculated from solids analysis.
Solids compositions were those of the gasifier and
regenerator beds. It is apparent that sulphur production
values based on the solids analysis are much higher than the
gas analysis based figures. Similarly, the calculated
values for oxidation selectivity are much higher when based
on solids analysis. The solids based selectivities for this
run are in good agreement with the gas analysis based
selectivities of Run 3 (Figure 38 of Reference 1).
- 71 -
-------
Table 13
Summary of Regenerator Performance
ro
i
Time
3.1530
3.2230
5.1O3O
6.0730
12.1630
12.1830
13.0430
13.0630
17.1130
21.0730
21.1830
22.0730
22.1730
25.0530
25.1430
26.0430
26.1030
26.1800
2.89
2.72
3.66
3.72
2.88
2.80
2.76
2.53
3.11
2.69
2.85
2.90
2.91
2.74
2.52
2.74
2.70
2.87
Run 5
Selectivity
Solids % CaS to CaO
. % Gas Solids
Regenerator Analysis Analysis
1.82 27.8 50.5
1.81
1.59
1.84
1.85
1.80
2.06
1.83
1.00
1.78
1.75
2.21
1.91
1.88
1.72
2.17
1.96
1.96
37.6
40.9
40.5
30.4
32.8
37.2
34.2
44.0
28.2
50.0
32.5
40.0
32.0
26.8
27.5
34.1
31.3
52.9
70.5
61.0
59.2
53.5
40.7
40.7
78.1
50.0
64.3
46. 0
56.2
43.7
53.3
34.5
44.8
5O.6
Regenerator S
By Gas
Analysis
kcL/Hr. % of Fed
1.30
1.73
1.94
1.63
1.59
1.76
2.06
1.92
2.26
1.38
2. OS
1.51
1.84
1.6C
1.22
1.43
1.77
1.52
30.8
39.7
44.3
38.9
36.5
40.7
47.8
45.2
51.7
26.9
4O.7
34.1
40.9
37.4
27.3
31.8
39.2
34.0
ulphur Ou
By £
Anal
kg/Hr
2.52
2.46
3.55
2.65
3.36
3.03
2.29
2.33
4.36
2.62
2.81
2.19
2.70
2.34
2.63
1.85
2.40
2.64
itput
iolids
.ysis
% of Fed
59.4
56.6
81.1
63.1
77.1
70.2
53.4
54.8
99.5
50.9
54.9
49.6
59.9
52.3
59.1
40.2
53.0
58.9
Gasifier
SRE
%
72.8
60.5
93.8
96.6
84.6
86.1
87.9
88.2
80.5
92.9
87.3
90.9
85.2
95.7
9O.6
88.9
90.8
85.4
-------
In Run 5 the level of sulphur in the bed was relatively
low compared with the sulphur content of the cyclone fines.
With the external cyclone fines return system these fines
had little chance to be regenerated. In Run 3 however, fines
from one cyclone drained to the regenerator. This arrange-
ment must have decreased the sulphur content of the
circulating fines and reduced the effect of fines loss to
the boiler on sulphur removal efficiency.
Sulphur Balance -
Use of the gas analysis figures for regenerator sulphur
output leads to very low sulphur material balances for the
unit. Assuming that measured values of sulphur removal
efficiency are correct, it is not possible to account for
the missing sulphur by assuming that it left with the lime
purge stream of fines losses. A fault in the regenerator
off gas analyser could explain the discrepancy, but checks
and calibrations made on the instrument during the run
indicated that it was functioning properly. Similarly, a
larger gas flow through the regenerator than measured would
cause a low estimate of sulphur production.
Such a large error in gas measurement is unlikely because
air to the regenerator is measured both by orifice and
gas meter, nitrogen to the solids transfer system is
metered, and nitrogen to instrument bleeds is negligibly
small. The only other possibility is a major leakage from
gasifier to regenerator, and again this is believed unlikely.
To help solve this mystery, additional analyses and measure-
ments were planned for future runs, including checking of
gas flow rate out of the regenerator by a helium tracer
method, and use of a gas chromatograph to check regenerator
gas composition for SC>2 and other sulphur compounds.
Plans were also made to modify the boiler flue gas sampling
system to reduce further the possibility of losing sulphur
in the sample lines and filters. It is possible that S02
is absorbed on lime dust which enters the sample line, and
such absorption would produce an optimistic estimate of
sulphur removal efficiency. Such errors are believed to
be small however, as the lines are frequently cleaned, and
spot checks with Draeger tubes (direct reading SC>2 colour
change tubes) made directly through the boiler door sample
point agree with the continuous reading instrument.
- 73 -
-------
Run 6
Equipment Performance is described in Appendix C, Run Log
and Post-run Inspection. Overall performance was improved
over previous runs and the pilot plant gasifier was more
easily held at steady conditions to record lined-out data.
The single fuel injector was tested during Run 6 and
mechanically performed well. No symptoms of defluidisation
were noted, but desulphurisation efficiency fell sharply.
The divided gasifier plenum was used during the test of the
single fuel injector to assess whether an induced bed
circulation would assist desulphurisation. No effect was
noted.
Restoration of the right hand gasifier cyclone drain into
the gasifier to regenerator bed circulation line in itself
posed no new problems, and none were expected as this was
the original design for fines return from this cyclone. The
purpose of this modification from Run 5 was intended to
direct more fines into the regenerator, and thus to remove
their sulphur burden and prevent SC>2 release into the boiler.
However, as discussed below, it appeared from the post run
inspection that the right hand cyclone drain was completely
blocked for the latter part of the run, but no corresponding
decrease in sulphur removal efficiency was observed.
During Run 6 the longest uninterrupted period of gasification
was 193 hours - a substantial improvement over Run 5. Run 6
process performance is discussed below in conjunction with
Run 7.
Process Performance, Runs 6 and 7 -
General Considerations. The Sulphur Removal Efficiencies
measured during Runs 6 & 7 agreed reasonably well with those
measured during previous runs at lime replacement rates less
than 1 mol Ca/mol S but were considerably lower than was
anticipated at higher lime replacement rates. The reason for
this divergence seems to be that the S02 concentration in
the flue gas samples prior to Runs 6 and 7 was dependent on
the amount of lime dust in the flue gas, which in turn
depended on the stone replacement rate. Modification to the
flue gas sampling system made prior to Run 6 and changes in
the monitoring procedure eliminated this source of error and
the running sulphur balances for Runs 6 and 7 (Appendix Tables
C.II and D.VI) are well within the calculated margin of
experimental error (Appendix J).
- 74 -
-------
Because the S.R.E.s measured in Runs 6 and 7 are considered
to be the most reliable, they have been used in order to
deduce which are the raajor factors affecting the desulphur-
ising performance of the gasifier. Comparisons between the
results obtained during these two runs must however take
account of changes in reactor geometry, process flow plan
and bed material which were made between the runs. These
changes were undoubtedly important since, as will be shown
later, the results obtained during Run 6 were significantly
better than those obtained during Run 7, despite the fact
that the mean superficial gas velocities during the two sets
of test periods were respectively 1.29 m/sec and 1.15 m/sec.
A major geometrical change arose from the installation of
heat exchanger tubes in the gasifier bed for Run 7. These
tubes were made in the form of portal frames and were
retractable. In order to accomodate them the two stage low
efflux velocity nozzles of the air distributor which were
installed for Run 5 had to be discarded in favour of the
smaller diameter single stage nozzles which were used prior
to Run 5. It was incidentally the installation of the heat
exchanger tubes in the gasifier bed which resulted in the
reduced gas velocities observed in Run 7 at fuel throughputs
comparable with those for Run 6 and at marginally leaner
air/fuel ratios. The reason for this is that the requirement
for recycled flue gas for temperature control was reduced in
Run 7 by the operation of the heat exchanger. So far as
process flow plan is concerned, in Run 6 the fines collected
by the regenerator cyclone were discarded, whereas in Run 7
they were reinjected into the gasifier bed. The object of
this measure was to improve fines retention.
In both runs the left hand cyclone was drained externally
but the right hand cyclone was drained into the gasifier to
regenerator transfer fine. Considerable trouble was
experienced with the cyclone fines return systems in both
runs and in both cases there were extended periods of
operation during which fines were not returned to the
gasifier bed, without any obvious ill effects in terms of
S.R.E•
Stone BCR 1359 was used during all of the lined out test
periods reported for Run 6 whereas most of the results
reported for Run 7 were obtained using Denbighshire stone.
The three sets of results reported after day 12 of Run 7
were obtained using BCR 1359 feed and these are perhaps
marginally better than the rest of the results in this test
series.
- 75 -
-------
Variables of Major importance. The test results for Runs 6
and 7 are reported in Tables 14 and 15. All of these results
were obtained by averaging sequences of ten hourly sets of
data during a more extended period of stable operation. The
test periods may be located in Appendix Figures CIS and D25
by the times listed for the first of each set of
observations in Tables 14 and 15. The first number in the
time sequence relates to the day, and the subsequent four
figures give the time on the 24 hour clock.
Gross effects have been detected by plotting individual
independent variables against sulphur removal efficiency.
Thus in the case of Run 6 it may be seen (Fig.16) that there
is a trend for S.R.E. to improve as the gasifier bed is
deepened. There is however an ever stronger indication
(fig. 17) that gasifier performance improves as the sulphur
content of the bed material is reduced. The circled figures
against each point in (fig. 17) relate to bed depth and it
will be seen that there is no obvious correlation between
bed depth and bed sulphur content in this set of results.
This indicates that the two effects are independent of each
other. The uncircled figures against each point in (fig. 17)
relate to stone replacement rate (Ca/S ratio). In this case
there is a trend for low stone replacement rates to be
associated with high sulphur contents of the bed material,
this therefore casts some doubt concerning which of these
two variables caused the observed effect on S.R.E. This
question can however be resolved by refering to the
independent set of results obtained for Run 7. In this case
(or as can be seen in figs. 18 and 19), there is a tendency
for performance to improve as the bed is deepened and as its
sulphur content falls. In this set of results however there
is a tendency for deeper beds to have lower sulphur contents
so that if these two effects had not been shown to be
independent in Run 6 there would have been some doubt as to
which was important. The figures shown against the plotted
points in (fig. 19) again relate to stone replacement rate.
In this case there is no obvious relationship between stone
replacement rate and bed sulphur content and consequently
S.R.E*
Taking the two sets of results together the indications are
that the variables of major importance are bed depth and bed
sulphur content. This doesn't mean that the other variables
under consideration such as stone replacement rate, bed
temperature and air/fuel ratio have negligible effects, but
these effects do seem to be of secondary importance.
- 76 -
-------
Table 14. AVERAGED RESULTS FOR SELECTED 1O HR PERIODS
RUN 6
Time
of First
Reading
2-O83O
3-O43O
6-2230
8-0430
9-OO3O
11-0630
12-2030
15-1330
16-1930
19-1730
S.R.E.
%
75.5
8O.O
8O.O
71.5
71.5
84.0
82.0
82.0
71.5
78.5
Bed
Depth
cm
55
6O
53
51
53
58
50
56
42
43
Ca/S
Mol
Ratio
0.9
1.1
1.4
0.4
0.6
2.2
1.4
1.2
1.5
1.1
Bed
Temp
"C
874
914
889
9O5
905
883
880
870
880
874
Superficial
Gas Vel.
m/sec
1.29
1.42
1.34
1.29
1.16
1.26
1.30
1.28
1.27
1.24
Air /Fuel
Ratio
% stoic
20.5
22.8
22.1
20.5
21.0
22.5
21.6
21.3
21.0
20.8
Stone
BCR 1359
ii
ii
n
M
ii
n
n
n
n
Bed
Sulphui
%wt
5.1
5.O
4.7
6.3
5.5
-
4.5
4.3
-
-
Bed
Carbo
%wt
0.19
0.17
O.1O
0.36
0.45
-
0.02
O.10
-
-
Re gen
Selectivity
%
81.9
62.3
74.3
88.3
70.7
63.0
55.2
58.2
50.1
65.6
-------
Table 15.
AVERAGED RESULTS FOR SELECTED 10 HR PERIODS
RUN 7
Time
of First
Reading
4-0630
5-0230
6-1830
7-1430
9-2130
11-0930
13-0030
13-1530
14-1630
5 . R. £ .
77.5
80.0
67.5
67.5
7O.O
78.0
81.0
8O.O
77.0
Bed
Depth
cm
60
61
53
53
49
56
60
55
54
Ca/S
Mol
Ratic
0.80
O.8O
0.50
0.75
1.40
1.40
2.40
1.20
1.O3
Bed
Temp
°C
888
918
914
902
922
9O9
914
924
878
Superficial
Gas Vel.
=• m/sec
1.11
1.25
1.20
1.17
1.10
1.15
1.12
1.14
1.08
Air /Fuel
Ratio
% Stoic.
21.3
23.2
22.2
22.1
22.2
23.2
25.0
23.3
22.2
Stone
Denbigh-
shire
6OO-32OO
_ n. —
Denbigh-
shire
3OO-2OOO
y
Denbigh-
shire
6OO-32OO
y
_ » _
BCR 1359
_ n _
- " -
Bed
Sulphur
%wt
3.4
3.9
5.5
5.6
5.1
4.3
3.3
3.6
5.5
Bed
Carbon
%wt
0.53
0.45
0.85
0.85
O.O8
O.O6
O.O6
0.14
0.21
Re gen
Selectivity
75.8
82.2
74.3
68.4
68.0
80.6
73.6
73.7
71.5
oo
I
-------
90
80
u
tr'
70
60
RUN 6
S.R.E. VERSUS BED DEPTH
NUMBERS SHOW Co/S RATIO
1-5
40
• 0-9
• •o-e
0-4
O SINGLE FUEL
INJECTOR
(ONE WAY)
I
50
BED DEPTH ems
60
Figure 16 Sulphur Removal Efficiency vs Bed Depth
(Run 6)
- 79 -
-------
90
80
UJ
or
70
60
RUN 6
S.R.E. VERSUS BED SULPHUR CONTENT
PLAIN NUMBERS SHOW Co/S RATIO
RINGED NUMBERS SHOW BED DEPTH
O SINGLE FUEL INJECTOR
(ONE WAY)
I
I
I
456
% WT SULPHUR ON BED
Figure 17 Sulphur Removal Efficiency vs Bed Sulphur
(Run 6)
- 80 -
-------
RUN 7
90
80
70
60
40
S.R.E, VERSUS BED DEPTH
• DENBIGHSHIRE STONE
A B.C.R. 1359
NUMBERS SHOW Co/S RATIO
Al-2
SINGLE
FUEL INJECTOR O
(6 WAY)
1-4
0-75
50
BED DEPTH cms
60
Figure 18 Sulphur Removal Efficiency vs Bed Depth
(Run 7)
- 81 -
-------
90
80
UJ
a:
70
60
RUN 7
S.R.E.VERSUS BED SULPHUR CONTENT
• DENBIGHSHIRE STONE
A B.C.R. 1359
NUMBERS SHOW Co/S RATIO
(•2
•0-8
(•4
A 1-03
0-5 •• 0-75
% WT SULPHUR ON BED
Figure 19 Sulphur Removal Efficiency vs Bed Sulphur
(Run 7)
- 82 -
-------
If a gross overall comparison is made between the sets of
test results for Runs 6 and 7, it becomes obvious that Run 6
gave a significantly better performance than Run 7. In fig.
20 the two bed depth/S.R.E. relationships are plotted on
common coordinates. Although the Run 6 results are very
scattered, indicating a major effect for another variable,
they are on the whole better than those obtained during Run 7.
The trend lines for the two groups of results tend to converge
as the beds became deeper. This probably results from the
correlation between bed depth and stone sulphur content in
Run 7 which exagerates the effect of bed depth. Even if the
trend for Run 6 is more realistic however, the indications
are that substantial approvements in S.R.E. should be
obtainable with gasifier beds more than 6O cm deep.
In fig.21 the two bed sulphur content/S.R.E. relationships
are plotted on common coordinates. In this case there is
clear evidence that Run 6 gave a better result for any given
sulphur content than Run 7, and there is a strong indication
that bed sulphur contents of less than 4% by weight will prove
to be advantageous.
The most obvious explanation for the gross difference in
performance between Runs 6 and 7 is a difference in the
reactivities of the stones which were used. The Run 6
results listed in Table 14 relate entirely to BCR 1359,
whereas in Run 7 Denbighshire stone was used up to May 12
and only then was the feed switched to BCR 1359. It will of
course take a considerable time for a change in stone feed
to have an appreciable effect on bed composition and it was
during the period starting 14-163O in Run 7 that an anomalous
result was obtained for a high bed sulphur content which is
typical of results obtained during Run 6. This explanation
is necessarily very tentative in view of the paucity of the
evidence, but it does account for a very atypical result
obtained during Run 7.
Variables of Minor Importance. The stone feed rate does
appear to have an effect on S.R.E. but rather less of an
effect than was anticipated, bearing in mind the results
of the batch tests. The magnitude of the effect may be
gauged from Figs. 16 and 18. In both these cases the
numbers against the plotted points relate to stone replace-
ment rate and in both cases the values below the trend line
are lower than those above the trend line. Unfortunately,
in both cases the lowest stone replacement rates are
associated with the highest stone sulphur contents so that
- 83 -
-------
90 i—
RUNS 6 AND 7
TREND LINES FOR S.R.E.
VERSUS BED DEPTH
80
UJ
o:
CO
70
60
RUN 6
RUN 7
I
40
50
BED DEPTH cms
60
Figure 20 Sulphur Removal Efficiency vs Bed Depth
(Runs 6 and 7)
- 84 -
-------
90 r-
RUNS 6 AND 7
TREND LINES FOR S.R.E.
VERSUS SULPHUR ON BED
80
UJ
•
QC
70
60
I
1
I
456
% WT SULPHUR ON BED
Figure 21 Sulphur Removal Efficiency vs Bed Sulphur
(Runs 6 and 7)
- 85 -
-------
the effect of stone replacement rate as shown in figs 16
and 18 may well be somewhat exaggerated. From a purely
practical point of view it is advantageous to minimise
stone consumption and the indications are that stone
consumptions less than stoichiometric may be anticipated.
The bed temperatures listed in Tables 14 and 15 do not appear
to relate strongly with S.R.E. In the case of the Run 7
results there are two pairs of virtually identical bed
depths and stone sulphur contents. These occur in periods
4-O63O and 5-O23O and periods 6-183O and 7-1430. In the
first pair of periods the stone feed rate is also constant,
the only significant variables being bed temperature and
air/fuel ratio, which tend of course to be related. A
comparison of the S.R.E. values for these two test periods
shows an apparent improvement in performance when the gasifier
temperature is increased from 880°C to 918°C. In the case
of the second pair however no improvement is seen when the
gasifier temperature is raised from 9O2°C to 914°C but a
slightly higher stone feed rate is associated with the
lower temperature.
Such evidence as there is from Run 6 tends to be equally
contradictory. If on the one hand period 6-223O is compared
with period 12-2O30 then raising the bed temperature from
88O°C to 889°C appears to have an adverse effect. If on
the other hand period 12-2O30 is compared with period 15-1330
then the effect of an increase in temperature from 870 °C to
880°C seems to have balanced out the deterioration in
performance which would otherwise have resulted from a
reduction in bed depth from 56 cms to 5O cms. A possible
explanation of these apparent contradictions may be that
these are two favourable zones of operating temperature, one
peaking at about 880°C the other peaking at about 9O8°C.
It seems reasonable however to conclude that the S.R.E. of
the gasifier is not unduly sensitive to variations in
operating temperature in the range 87O - 92O°C.
Effects of variations in fuel injection on S.R.E. Prior to
Run 6 fuel oil had been injected into the gasifier through
three downward sloping side nozzles. The same fuel injection
system was used throughout most of Runs 6 and 7 but in both
of these runs the gasifier was provided with an additional
retractable fuel injector protruding through the distributor.
In Run 6 this retractable injector was used during the
period 13-180O to 15-030O whilst in Run 7 it was used during
the period 16-1715 to the end of the run at 17-23OO.
- 86 -
-------
The retractable nozzle used in Run 7 differed in geometry
from that used in Run 6. In both cases the fuel was
injected horizontally with the assistance of an air blast
but whereas in Run 6 all of the fuel entered via a single
orifice, in Run 7 the retractable nozzle was provided with
six radial holes. The positions of the retractable nozzles
also differed. In Run 7 the nozzle was fitted in the centre
of the air distributor whereas in Run 6 the nozzle was offset
to a position about \ of the length of the gasifier bed from
its L.H. end. In Run 6 the single orifice was aligned along
the axis of symmetry of the gasifier bed so that the
direction of fuel injection was from left to right.
The S.R.E. during the Run 6 test period 14-133O, Table 16 which
was run whilst the single orifice was being used, was only
66% despite a bed depth of 58 cms and a bed sulphur content of
only 3.4%. This may be compared with an S.R.E. of 82% for
the test period 15-133O when the bed was 56 cms deep and
its sulphur content was 4.3% and another S.R.E. of 82% for
the test period 12-2030 when the bed was only 50 cm deep and
its sulphur content was 4.5%. It can be seen in fig. C.15
that there waS an immediate reduction in S.R.E. when the
single nozzle was brought into use and that there was a
rapid recovery in S.R.E. when the single nozzle was replaced
by the three injectors originally used. During this period
the divided gasifier plenum was used to induce "gulf
streaming", and flow patterns in the bed. No effect was
seen.
The effect of using the single injector during Run 7 was
much less pronounced than that which was seen during Run 6
though as is shown in Fig. D.25 there does appear to have
been a slight drop in S.R.E. after the change to a single
injector was made at 16-2040. During the ten hour period
commencing at 17-0430 (table 16) the S.R.E. was 74%, the bed
depth being 54 cms and the bed sulphur content being 6%.
This may be compared with an S.R.E. of 77% for the test period
14-163O when the bed depth was again 54 cms and the bed
sulphur content was 5.5%. The difference in S.R.E. in these
two cases might well be accounted for by the slight difference
in the bed sulphur contents.
In both Run 6 and Run 7, the fuel was initially injected
from the single injector 11 cms above the plane bisecting
the nozzles of the air distributor, this being the height of
the three side fuel injectors. During Run 6 this height was
not changed but during Run 7 an attempt was made to improve
- 87 -
-------
Table 16. RESULTS WITH SINGLE FUEL INJECTORS
RUNS 6 & 7
RUN NO
Time
S • R. £ •
Bed
Depth
cm
Ca/S
Mol Ratio
Bed
Temp
•C
Superficial
Gas Vel.
m/aec.
Air /Fuel
Ratio
% Stoic
Bed
Sulphur
%wt
6
14-1330
66. 0
58
1.1
862
1.29
20.4
3.4
7
17-0430
74.0
54
0.9
897
1.01
20.1
-
- 88 -
-------
the performance of the gasifier by lowering the fuel injector
5 cms in two steps of 2.5 cms each. This had little if any
effect on S.R.E. but at the lower level the temperature of
the gasifier bed tended to fluctuate in an irregular fashion.
An attempt was made to raise the injector above its original
height but unfortunately it jammed in its sleeve and couldn't
be shifted.
In view of the important influence of bed depth on sulphur
removal efficiency it is desirable to establish whether bed
depth and fuel injection level are interchangeable. If
sulphur is mainly lost due to internal reflux within the bed,
resulting from the oxidation of sulphide at the distributor,
then a decrease in bed depth should have a greater effect
than raising the fuel injector an equivalent height. If on
the other hand sulphur is lost from the bed surface above
the fuel injector point then the effects of varying bed
depth and fuel injector height should be equivalent.
The effect of stone size on S.R.E. During Run 7 a specially
sized batch of Denbighshire stone was substituted for the
normal stone feed for a period of about 24 hours. This batch
of stone was sized in the range 3OO-2OOO microns as against
the 60O-32OO microns normally used and the purpose of the
experiment was to determine whether S.R.E. is affected by the
size of the bed material.
The results of this experiment may be assessed by comparing
the data for test periods 6-1830 and 7-1430 (Table 15). It
will be seen that the depth of the bed and the sulphur content
of the bed material were equal during the two test periods
and that the air/fuel ratio was also unchanged. The stone
feed rates were not equal, that for the fine stone feed being
O.75 Ca/S whilst the coarse stone was fed at a Ca/S ratio of
only 0.5. In consequence of the differing stone feed rates,
the bed temperature when the coarse stone was used was
slightly higher than when the fine stone was used. 914°C
against 9O2°C. On the face of things it was to be expected
that the combination of a higher stone feed rate and a
smaller stone size would improve the S.R.E. In fact however
the two results were identical at 67.5%. It is therefore
reasonable to conclude that if the size of the stone feed
does have an effect, it is a very small one.
Further independent evidence of the relatively minor effect
of stone particle size on S.R.E. was obtained during Run 6
when three sets of gasifier and regenerator bed material
samples were sieved into six fractions and these fractions
- 89 -
-------
were analysed for sulphur content. The results which were
obtained are shown in Table 17 and it will be seen that,
again contrary to expectations, the coarser stone fractions
contained more sulphur than the finer ones although the
average differences in sulphur content between the gasifier
and regenerator samples were evidently independent of particle
size.
Possible explanations for these observations are that the
external surfaces of the particles take up a substantial
proportion of the sulphur, and that finer particles are
deactivated more rapidly than coarser particles. Since it
is easier to retain coarse particles than fine particles there
seems to be little incentive to use a finer bed material than
is necessary to ensure good fluidisation at the optimum
superficial gas velocity within the gasifier bed. In view
of the importance of this finding however it is considered
desirable to obtain confirmatory evidence in future runs.
Run 7
Equipment Performance is fully described in Appendix D
Operational Log and Inspection. Overall performance was
again improved over Run 6, and the longest period of
uninterrupted gasification reached a new peak of 211 hours
in the second part of the run. The first part consisting of
a single gasification period of 165 hours.
The modified gasifier distributor, with its single multi-
port fuel injector, and two water cooled heat transfer tubes.
performed fairly well. The test of fuel injector height had
to be abandoned when the injector jammed in position, but
the effect of one injector on process performance was
negligible. The water cooled tubes performed as expected,
but because of a slight upward displacement of the front
tube the cooling effect on the bed throughout the run was
too great to allow the planned series of tests to take place.
For considerable periods no flue gas recycle was used for
temperature control.
Cyclone performance was again poor, as shown in the post-run
inspection, and improvement of cyclone performance was
identified as of prime importance in future runs.
The regenerator distributor worked well, and no agglomerated
material was found on it in the post-run inspection. Despite
the modification to the flue gas recycle scrubber, plugging
of the drain occurred. An alarm will be installed for future
runs.
- 90 -
-------
Table 17. Sulphur Distribution in Bed Material Size Fractions
I
vo
1— •
+
,
Size
Range
Microns
>14OO
1180-1400
850-1180
600-850
25O-6OO
<250
Bed
Sample 1
S % by wt.
5.74
4.76
4.51
4.14
3.51
3.47
Regen
Sample 1
S % by wt.
4.70
3.70
3.14
2.91
2.04
1.77
Bed
Sample 2
S % by wt.
6.19
4.87
4.42
3.85
3.14
3.15
Regen
Sample 2
S % by wt.
3.65
3.95
2.94
2.30
1.79
1.67
Bed
Sample 3
S % by wt.
4.65
4.18
3.62
3.69
2.93
3.95
Regen
Sample 3
S % by wt.
3.61
3.62
2.91
2.91
2.46
3.43
Average
AS
% by wt.
1.45
0.85
1.19
1.19
1.10
1.2O
-------
TASK II - BATCH STUDIES
In the original programme of work for this contract, batch
units were to be used to determine the suitability of
additional fuel - limestone combinations for CAFB applications
It was envisaged that four new limestones would each be
studied with two fuels, one of which would be a vacuum
pipestill bottoms. Neither Denbighshire nor BCR 1691 stones
would be tested during this contract but earlier results on
these stones would be used as a basis for comparison. Two
of the stones were selected by EPA. These were BCR 1359
limestone and Tymochtee Dolomite. The other two were
selected by New England Electric System (NEES) and were
Pfizer Calcite and Pfizer Dolomite.
However, the following developments during the contract
dictated that the programme be altered. Firstly, Run 4
operations revealed a serious attrition problem with BCR
1691 during start-up which did not appear in earlier batch
unit tests. Previously, comparisons of dust losses between
stones had been confined to gasification - regeneration
cycles. No such comparisons had been made under fully
combusting conditions. In the normal batch unit test
procedure there had been little exposure of solids to
combustion conditions in the absence of sulphur except
during calcination. Consequently, the conditions employed
during Run 4 start-up produced an entirely unexpected result
in that BCR 1691 stone formed copious quantities of a dust
with a very sticky nature. Secondly, considerable interest
arose in operating CAFB with even heavier feedstocks than
vacuum pipestill bottoms. The actual material proposed was
a high sulphur petroleum pitch.
In order to accomodate the extra work resulting from these
developments without extending the programme, testing of
one of the EPA stones (Tymochtee Dolomite) and some of the
stone/fuel combinations was dropped. The objectives for
the revised batch unit test programme are listed below:
• Determine if continuous unit conditions which
produced large quantities of sticky dust could
be duplicated in batch units.
• Compare dust producing tendencies of Denbighshire
and BCR 1691 stones under a variety of conditions.
- 92 -
-------
• Provide a quantitative measurement of dust
production to be expected under start up and
operating conditions with Denbighshire, BCR 1691
BCR 1359, Pfizer Calcite and Pfizer Dolomite.
• Measure sulphur absorption performance of BCR 1359,
Pfizer Calcite and Pfizer Dolomite.
• Conduct tests of the feasibility of operating CAFB
with vacuum pipestill bottoms and High Sulphur Pitch.
The actual test programme which was carried out (Table 18)
did not, in fact, include any tests on Pfizer Dolomite as
Westinghouse had advised us that this stone decrepitated so
badly on calcination that it was not worth testing.
Additional tests on the heavy feedstocks were carried out
instead.
The investigation into fines production rates and properties
was based very much on our experience in Run 4. There, fines
produced from BCR 1691 under fully combusting conditions
did not drain freely from cyclones, whereas those produced
under gasifying conditions did.
It was suspected that the higher resistance to flow of the
combustion fines was due to their containing a much higher
proportion of very fine particles. Why less of the very
fine particles should be produced during continuous
gasification and regeneration was not clear. It was
considered possible that the presence of sulphur on the
stone, the higher regenerator bed temperature, an ageing
effect or a combination of these could be the answer. Any
of these changes could have altered the particle surfaces
in such a way as to make them less susceptible to decrep-
itation.
In the tests on the heavier fuels, with their higher
Conradson Carbon contents, particular attention was paid to
the increased rate of carbon deposited on bed particles.
Fresh bed tests were carried out to determine the effects of
air/fuel ratio, oxygen enrichment and bed temperature on
this. Test 5-D was included for comparison purposes.
Stone Comparison Tests -
Four stones, Denbighshire, BCR 1691, BCR 1359 limestones and
Pfizer Calcite (Appendix 0) were compared in terms of sulphur
removal efficiencies (SRE), fines production rates and fines
- 93 -
-------
Table IB. Teat Proqra
carried out la CAFB Batch Units
I
VO
Teat Ston«
1 - A BCR 1691
1-8
1 - C
1 - D
1 - E
1 - P "
2 - A Denbighshire
through
2 - F
3 - A BCR 1359
3 - B
3 - C
3-D
3 - B
4 - A Pfizer Calclte
4 - B
4 - C
5 - A BCR 1359
5 - B
5 - C
5 - D
5 - E
« - A
6 - B
6 - C
Fuel
Amuay 2.5% S
fuel oil
Kerosene
Kerosene and
Amuay 2.5% S
fuel oil
Kerosene
Amuay 2.5% S
fuel oil
Kerosene
Amuay 2.5% S
fuel oil
Amuay 3% S
Vacuum Resid.
Amuay 2.5% S
Fuel oil
Aauay 3% S
Vacuum Resid.
High Sulphur
Pitch
Conditions
Calcination and prolonged
combustion at 87O deg. C
Same at 1O5O deg. C
Calcination and combustion
at 870 deg. C
Calcination and gasification
at 870 deg. C
Gasification - regeneration
cycles at 0.9 moles CaO/mole
Prolonged combustion using
cycled bed from Test 1-B.
Entire programme sane as in
Test 1 through step F.
Calcination and prolonged
combustion at 67O deg. C
Calcination and prolonged
gasification at 870 deg. C
Gasification - regeneration
cycles at 0.9 moles CaO/mole
Gasification - regeneration
cycles at 1.2 moles CaO/mole
Gasification - regeneration
cycles at 1.5 moles CaO/mole
Calcination and prologned
combustion at 870 deg. C
Objective
Measure fines Ions rate and properties of dust
produced with BCR 1691.
Same
measure lined out sulphur removal efficiency and
fines loss rate
Measure fines loss rate during kerosene combustion
in conditioned lime bed.
Measure fines loss rate under different sets of
conditions with Denbighshire atone.
Measure fines loss rate and properties of dust
produced with BCR 1359.
Measure lined out sulphur removal efficiency and
s. fines loss rate
S.
Gasification - regeneration
cycles at 0.9 moles CaO/mole
Prolonged gasification at
870 deg. C
Prolonged gasification with
25% excess oxygen at 9OO
deg. C.
Prolonged gasification with
25% excess oxygen at 9SO
deg. C.
Prolonged gasification at
870 deg. C.
Gasification - regeneration
cycles at 0.9 males CaO/mole
Prolonged gasification at
25% stolchiometrlc air
Prolonged gasification at
3O% stoichiometric air
Gasification - regeneration
cycles at 0.9 moles CaO/mole
Investigate effect of make-up with BCR 1359.
Measure fines loss rate and properties of dust
produced with Pfizer Calclte.
Measure lined out sulphur removal efficiency and
S. fines loas rate.
Measure sulphur removal efficiency and carbon
deposition.
Si
Measure lined out sulphur removal efficiency and
carbon deposition.
Measure sulphur removal efficiency and carbon
deposition.
Measure lined out sulphur removal efficiency and
S. carbon deposition.
-------
properties. Since fines production tests were carried out
under a variety of CAFB operating conditions, information
on the effects of operating conditions on fines production
was also obtained.
Sulphur Removal Efficiencies for the four stones were
compared by cycle tests. It was originally intended that
all stones would be tested at the same target conditions
listed below which include a bed replacement rate less than
1 mole CaO/mole S.
Air/Fuel Ratio (% of stoichiometric) 25
Gasification Temperature (deg.C) 87O
Bed Replacement Rate (mole CaO/mole S) 0.9
Bed Depth (cm w.g.) 38
Gas Velocity (m/sec) 1.83
Potential Sulphur (% wt) 2
Differential
Limestone Particle Size (microns) 600-3175
These were chosen to give SREs significantly less than 1OO%.
When successive cycles of gasification and regeneration are
carried out under such conditions, SRE falls for several
cycles and then lines out. Comparison values of SRE are
measured at the lined out level. However, with Pfizer Calcite,
bed losses were so high that this stone could not be tested
at bed replacement rates less than 1.5 moles CaO/mole S.
In addition to direct comparison of stones at a single set
of conditions, the effect of bed replacement rate on the
performance of BCR 1359 was also examined and compared with
previous data on BCR 1691. Detailed results of the tests
are listed in Appendix N. Results are summarised in Table 19.
Measured SREs were similar for BCR 1691, Denbighshire and
BCR 1359 stones at the lower bed replacement rate and for
BCR 1359 and Pfizer Calcite at the higher rate. However,
actual conditions did vary slightly from target conditions as
shown in the table and, therefore, for comparison, lined out
SREs were calculated for each of the test conditions for each
stone from the equation derived for BCR 1691 (Reference 1).
From the ratio of measured to calculated SRE, it appears that
the Denbighshire stone is slightly more active than the other
three which have similar activities.
- 95 -
-------
Tab la 19
I
\o
LIm>stons
Residence
Time
(sec)
BCR 1691 O.2O
Denbighshire O.17
BCR 1359 0.15
BCR 1359 0.18
BCR 1359 0.19
Pfiser Calcite O.16
P.S.D./
(wt %)
1.96
2.18
1.87
2.0O
1.76
1.81
Make-up Rate
CaO/S
wt. Mole
1.59 .91
1.49 .85
1.61 .92
2.05 1.17
2.83 1.62
2.71 1.57
SRE
(Measured)
%
75
76
76
79
89
89
SRE *
(Calculated)
78
65'
76
83
95
93
Ratio of
SRE (Meas'd)
to SRE (cal)
0.96
1.17
1.0
0.95
0.94
O.96
* Calculated from equation for predicting SRE's for BCR 1691.
/ Projected Sulphur Differential
-------
The tests on bed replacement rate indicated that this
variable has a significant effect on SRE of BCR 1359 although
comparison with calculated SREs for BCR 1691 show that the
effect may be less marked than with BCR 1691. These
conclusions must be somewhat tentative, however, as other
variables also changed slightly and the magnitudes of the
effect of each variable may very well be different with BCR
1359.
Fines Production Rate measurements were based on bed losses.
Table 20 summarises the bed loss results for the four
limestones under a variety of CAFB conditions. Detailed
results are given in Appendix N.
With BCR 1691, the highest bed loss rate occurred during
kerosene combustion with a fresh bed at 870°C. Loss rates
during fuel oil combustion and gasification where sulphur
was being absorbed by the stone were lower, those during
gasification where sulphur absorption was more rapid being
less than during combustion.
The sulphided and aged stone from the cycle tests also
showed a relatively low loss rate during kerosene combustion
at 87O deg. C. The lowest loss rate measured by tests of the
fresh bed type, however, was obtained during kerosene
combustion at 1O50 deg. C, the temperature level used in
regeneration. This was only slightly above the lined out
rate for the cycle tests in which the rate fell from 19.8
g/min in the first cycle to a stable level of 4.5 g/min
after 5 cycles. We can conclude, therefore that raising
bed temperature or introducing sulphur into the bed decreases
BCR 1691 loss rate. This explains the reduction in losses
observed when gasification was commenced in Run 4. Sulphur
had been absorbed by the bed which was also being subjected
to the high temperatures of regeneration. Prior to this, no
sulphur had been introduced to the bed since kerosene
combustion had been employed, and the regenerator temperature
was low since no reaction was taking place.
A bed ageing effect is also indicated. Hourly losses during
fresh bed tests decreased as the tests proceeded whilst loss
rate during cycle tests had fallen from 19.8 g/min to 4.5
g/min by 5 cycles. It is important to note, however, that
ageing during fresh bed tests is distorted to some extent
due to the fact that bed depth was decreasing during each
test. That bed depth has an important effect on loss rate
was established in the Phase 1 work (Reference 1).
- 97 -
-------
Table 2O
VO
oo
Test Test Condition
1-A Kerosene Combustion
1-B Kerosene Combustion
1-C Fuel Oil Combustion
1-D Fuel Oil gasification
1-E Gasification-Regeneration Cycles
1-F Kerosene Combustion Sulphided
Aged Bed
2-A Kerosene Combustion
2-B Kerosene Combustion
2-C Fuel Oil Combustion
2-D Fuel Oil Gasification
2-E Gasification-Regeneration Cycles
2-F Kerosene Combustion Sulphided
Aged Bed
3-A Kerosene Combustion
3-B Fuel Oil Gasification
3-C Gasification-Regeneration Cycles
O.9 moles CaO/Mole 5
3-D Gasification-Regeneration Cycles
1.2 moles CaO/Mole S
3-E Gasification-Regeneration Cycles
1.5 moles CaO/mole S
4-A Kerosene Combustion
4-B Fuel Oil Combustion
4-C Gasification-Regeneration Cycles
O.9 moles CaO/mole S
Summary of Batch Unit Fines Loss
Limestone
BCR 1691
It
"
N
"
•
Denbighshire
H
H
H
•
•
BCR 1359
•
"
It
N
Pfizer
Calcite
H
M
Temperature Total Solids Loss from Bed, grams Average Loss Rate over
deg. C 1 hour 2 hours 3 hours 4 hours 4 hours (tj/ mini
870 2900 4220 5OOO 543O
105O 555 960 122O 1360
87O 1110 1910 269O 3250
870 68O 1190 156O I860
850 - 1050 -
870 760 1300 17OO 2O4O
87O 500 760 93O 1O20
1050 520 680 75O 79O
870 1160 1600 1920 2160
87O 146O 193O 216O 2330
850 - 1050 -
87O 48 96 14O 188
87O 2OO 34O 44O 51O
87O 480 630 75O 81O
85O - 1O5O -
850 - 1050 -
85O - 1O5O -
87O 6OO 1060 138O 1640
870 850 1320 162O 18OO
850 - 1050 -
22.6
5.7
13.5
7.8
19.8/4.5 *
8.5
4.3
3.3
9.0
9.7
6.6/1.4 *
0.8
2.1
3.6
6.4/1.9 *
4.2/-*
-
6.8
7.5
10.0/6.3*
* First value is loss rate during 1st cycle, second is lined out loss rate after 5 cycles.
-------
The relative importance of all variables effecting bed loss
rate of BCR 1691 is summarised in the equation below. This
was derived from further analysis of the fresh bed test
results.
29.54 x D2'17
A0'44 x (T-750) ^xS °'41
L = Loss rate (g/min)
D = Bed Depth (cm)
A = Bed Age (hours)
T » Bed Temperature (deg. C) (750 deg. C is taken as
CaCOa decomposition temperature) .
S = Bed Sulphur Content including inherent sulphur
(% by weight)
This equation shows the approximately square relationship
between losses and bed depth as observed previously. The
loss rate of 3.1 g/min calculated from the above equation
for cycle test conditions is in fair agreement with the
measured rate of 4.5 g/min.
With Denbighshire stone fresh bed tests showed a decrease in
loss rate with increased temperature and an increase when
fuel was used instead of kerosene. The stable rate during
cycle tests was lower than for fresh bed tests. The lowest
rate, however was measured with aged, sulphided stone under
kerosene combustion.
In light of our experience with the two previous stones,
only kerosene combustion, fuel oil gasification and cycle
tests were studied with BCR 1359. The gasification fresh
bed test gave a higher loss rate and cycle tests a lower
rate than the fresh bed test with sulphur free kerosene
combustion.
With Pfizer Calcite only kerosene combustion, fuel oil
combustion and cycle tests were examined. Fuel oil
combustion gave a higher loss rate and cycle tests only a
slightly lower rate than the fresh bed test with kerosene
combustion.
The bed ageing effect which decreased losses with BCR 1691
was also evident with Denbighshire, BCR 1359 and to a lesser
degree with Pfizer Calcite. For example, within 5 cycles,
loss rate dropped from 6.6 g/min to 1.4 g/min with
- 99 -
-------
Denbighshire, from 6.4 g/min to 1*9 g/min with BCR 1359 and
from 1O.O g/min to 6.3 g/min with Pfizer Calcite. These
results reveal several interesting comparisons between the
stones. These are summarised in Table 21.
None of the higher purity stones gave the very high loss
rate found with BCR 1691 during fluid bed combustion with
kerosene at 870 deg. C. Both Denbighshire stone and BCR
1691 gave lower loss rates during kerosene combustion when
temperature was increased from 870 deg. C to 1050 deg. C.
Although the temperature effect was less dramatic for
Denbighshire, its loss rate remained below that of BCR 1691.
No high temperature tests were made with BCR 1359 or Pfizer
Calcite.
All four stones exhibited a decreasing loss rate with age
during the initial test periods. The change became less
significant at long exposure times. This age effect may be
due to a strengthening of particles by a sintering process,
to elimination of particles of lower initial strength, or
to a combination of these factors. The significant decrease
in loss rate at the higher temperature appears to be a
consequence of the more severe sintering which would be
expected under those conditions.
The effect of changing from kerosene to fuel oil differed
between the low purity and high purity stones. Whereas with
BCR 1691, fresh bed loss rate decreased when fuel oil
replaced kerosene combustion and decreased again on going
to fuel oil gasification, opposite directional results were
found with Denbighshire stone. Results from the shorter
test programme on BCR 1359 and Pfizer Calcite indicate that
their behaviour is similar to that of Denbighshire. In
spite of- its high loss rate during fresh bed gasification
the Denbighshire stone gave the lowest rate of the three
during gasification - regeneration cycles.
We believe that loss rate differences between kerosene and
fuel oil operation are due to sulphur in the oil. However,
the mechanism of the sulphur effect must be complex to
increase losses with the pure stones whilst decreasing
losses with the lower purity BCR 1691.
Although Pfizer Calcite behaved in a directionally similar
manner to changes in operating conditions as the other pure
stones the magnitude of its responses was considerably less.
We consider that the lower level of response results from
- 1OO -
-------
Table 21
SuBBMury of Batch Unit. Loss. Kates
Loss Rate (g/mln) *
Conditions :
Limestone
BCR 1691
Denbighshire
BCR 1359
Pfizer calcite
Kerosene**
Combustion
870 deg.C
22.6
4.3
2.1
6.8
Kerosene**
Combustion
1O7O deg.C
5.7
3.3
-
Fuel Oil**
Combustion
87O deg.C
13.5
9.0
-
7.5
Fuel Oil**
Gasification
870 deg.C
7.8
9.7
3.6
-
Kerosene Combustion
on Sulphided Aged Bed
87O def . C
8.5
0.8
-
-
Gasification
Regeneration
Cycles
4.5
1.4
1.9
6.3
At all conditions except gasification/regeneration cycles, loss rate has been calculated over the
first four hours of the test. The cycle loss rate is the stable loss rate.
** Fresh Bed Tests
-------
the major attrition mechanism being different with this
stone. As a result of its much larger crystallites,
attrition results principally from the fracture of these
whereas with the other stones it probably results mainly
from the separation of crystallites. In line with this the
much smaller reduction in loss rate with Pfizer Calcite
during gasification/regeneration cycles could very well be
due to the inability of the large crystallites to withstand
the thermal shock associated with changes between gasification
and regeneration conditions. Finally, on the basis of these
tests, we have concluded that Denbighshire and BCR 1359
stones are suitable for the CAFB process, that BCR 1691 is
unsuitable principally because of its high fines loss rate
under combustion conditions > which would be used for hot
standby in commercial applications, and that Pfizer Calcite
is unsuitable because of its high fines loss rate during
gasification/regeneration cycles. We postulate that the best
stones for the process have high purity but not large
crystallites.
In addition to the results already discussed, bed losses
were also measured during calcination and are summarised
in Table 22.
Table 22
Summary of Batch Unit Calcination Losses
Low Sulphur Fuel
Kerosene and High Sulphur Fuel
Stone propane * 2.3% $ Oil *
BCR 1691 18 15
Denbighshire 16 24
BCR 1359 6
Pfizer Calcite 18 21
Losses as % of calcined stone
The low calcination loss rate from stone BCR 1359 makes it
particularly attractive. The effects of sulphur on loss rate
in calcination of Denbighshire, Pfizer Calcite and BCR 1691
stones are in the same direction as observed in the fresh
bed tests with these stones.
- 102 -
-------
Properties of Fines were deduced from material collected in
the cyclone and deposited in pipes downstream of the cyclone.
Throughout the tests the cyclone operated satisfactorily
with the aid of a mechanical rapper, and regular samples of
fines were obtained. Table 23 contains the results of a
microscopic examination of these fines together with cyclone
efficiencies. With respect to physical appearance, the fines
have been separated into five groups. Examples from each
group are shown in Figures 22 to 26. The only fines
represented by Figure 22 are those collected during kerosene
combustion at 870 deg. C in BCR 1691. Most of the particles
appear to be less than 5O y. The fine particles seem to be
adhering to each other to form loose agglomerates and to the
surface of the few larger particles that are around. This
stickiness was also observed during kerosene combustion in
Run 4. Figure 23 shows the type of particles obtained when
BCR 1691 was subjected to kerosene combustion at 1050 deg. C,
to fuel oil combustion at 870 deg. C, and to gasification -
regeneration cycles followed by kerosene combustion at 87O
deg. C. There appears to be some larger particles in this
group and there is less evidence of the stickiness. In
Figure 24, the type of fines collected in all instances
where gasification or gasification/regeneration cycles were
carried out are illustrated. Due to the presence of carbon,
it is difficult to estimate the particle size range present.
However, it would appear that the great majority of particles
are less than 50 y. The fines collected under combustion
conditions with Denbighshire, Pfizer Calcite and BCR 1359
stones are represented in Figure 25.
In this case there is a discrete mixture of particles with a
maximum size around 10OO y. Finally, Figure 26 illustrates
the type of particles collected during kerosene combustion
at 870 deg. C of the sulphided, aged, Denbighshire bed.
Here, there is a discrete mixture of particles which are
mainly in the size range 50-10OO y.
These results indicate an approximate correlation between
fines product rate and particle size of the fines collected
by the cyclone. The large cyclone particles were collected
at the lowest production rate i.e. during kerosene combustion
of sulphided, aged, Denbighshire stone. Also it would appear
that kerosene combustion at 870 deg. C in BCR 1691 which
gave the highest fines production rate resulted in the
smallest particles being collected in the cyclone.
- 103 -
-------
Table 23
Nature of Cyclone Fines from Batch Unit Studies
Test Condition
Limestone
Kero combustion 870 deg.C BCR 1691
Kero combustion 1050 deg.C "
Fuel oil combustion 87O deg.C "
Fuel oil fasification "
i70 deg. C
Gasification/Regeneration "
Cycles
Kero combustion-sulphided "
aged bed 870 deg. C
Kero combustion B7O deg.C Denbighshire
Kero combustion 1050 deg.C "
Fuel oil combustion "
870 deg. C
Fuel oil gasification
87o deg. C
Gasification/Regeneration
Cycle* "
Appearance Size
Loose agglomeration of 99» <50Ai
particles less than 5O /u
Mainly discrete particles 90% <5O M
less than 50 /u
Mainly discrete particles 9O% < 5O/u
less than 5O /u
Mixture of carbon t Lime
Mixture of carbon » Lime
Mainly discrete particles 90% <50/u
less than 5O /u
Discrete mixture of particles -1OOO M
up to 1000 -u
-10OO>M
" - 10OO M
Mixture of carbon t Lime
Mixture of carbon A Lime
Cyclone Efficiency
8O
1OO
32.6
40. 1
83.9
59. 5
79. 4
62 .0
49.8
56.6
1OO
Kero combustion - sulphided "
aged bed 870 deq. C
Kero combustion B7O de? c BCR
Kuel oil gasification
170 deg. C
Gasification/Regeneration
Cycles
Kero Combustion 870 deg. C Pfizer
Calcite
'Fuel oil combustion
870 deg. C
Gasification/Regeneration
Mainly particles greater 90« > 50 /u
than 5O /u
Discrete mixture of particles -10OO«
up to 100O AI
Mixture of carbon i Lime
Mixture of carbon t Lime
Discrete mixture of
particles up to lOOOy
Mixture of carbon I lime
-lOOOu
44.4
86. )
83.0
1OO
96.6
- 1O4 -
-------
Figure 22 Cyclone Fines - BCR 1691 (Kerosene Combustion
870 deg. C.)
Figure 23 Cyclone Fines - BCR 1691 (Kerosene Combustion
1O50 deg. C. Fuel Oil Combustion 87O deg. C.,
Kerosene Combustion 87O deg. C on aged bed).
- 105 -
-------
Figure 24
Cyclone Fines - BCR 1691, BCR 1359 Pfizer Calcite
and Denbighshire (Gasification - Regeneration
Cycles)
Figure 25
Cyclone Fines - BCR 1359 Pfizer Calcite and
Denbighshire (All Combustion Conditions)
- 106 -
-------
Figure 26
Cyclone Fines - Denbighshire
(Kerosene Combustion 870 deg. C,
on conditioned bed)
- 107 -
-------
It is not possible, however, to extend this argument and
correlate fines production rate with particle size of total
fines produced because of differences in cyclone efficiency.
One of the lowest cyclone efficiencies was recorded for
the large cyclone particle sizes and one of the highest for
the smallest cyclone particle size. If particle size of
cyclone material was a true reflection of particle size of
fines produced by the bed, then one would have expected
cyclone efficiencies to have been highest with the largest
particle size. Why cyclone efficiency should act in this
way is indeed puzzling. However, it does mean that this
information of fines size and appearance cannot be used with
respect to fines production mechanisms.
Further tests on the fines collected showed that those
collected during gasification flowed best and equally well
for all four stones. Under all other conditions those from
BCR 1359, Pfizer Calcite and Denbighshire flowed more freely
than those from BCR 1691. The superior flow characteristics
of fines from gasification are attributed to their high
carbon content which could be as much as 45% by weight. The
superior flow characteristics of fines from Denbighshire,
Pfizer Calcite and BCR 1359 stones in relation to BCR 1691
under all the other CAFB conditions are attributed to the
presence of fewer of the very fine particles. Although
these differences were encountered in the flow properties
of the fines, we never encountered batch unit fines with the
severe stickiness of pilot plant fines made during Run 4
startup with BCR 1691.
Batch unit fines and bed samples from BCR 1691 were analysed
for calcium and silicon. The results showed that the batch
unit conditions also caused the preferential loss of calcium
from the bed observed in pilot plant Run 4. It appeared
to begin during calcination and continue through the tests.
As in the pilot plant, calcium lost from the bed did not
appear in recovered fines but was lost from the system. The
extent of calcium loss in the batch unit tests was not as
great as found in the pilot plant where the SiO2/CaO ratio
increased to 0.41 compared with an initial value of 0.27.
In batch unit cycle tests, the Si02/CaO ratio lined out at
approximately 0.33.
During each test unit pressures were monitored to determine
if any blockages were occurring downstream of the bed and
after each test exit gas lines were dismantled and examined.
Only one blockage of any significance was ever encountered.
This occurred with BCR 1691 under kerosene combustion
- 108 -
-------
conditions at 870 deg. C and was traced to a period of
cyclone rapper malfunction. This emphasises the importance
of fines concentration in the gas stream in relation to
blockages and shows that even with BCR 1691's high rate of
sticky fines production, proper draining of cyclones with
the aid of rappers where necessary prevents blockages.
Heavy Fuel Tests -
The object of these tests was to investigate the feasibility
of operating the process with heavy fuels such as Amuay
Vacuum Pipestill Bottoms and High Sulphur Pitch. If the CAFB
process could be made to operate satisfactorily with these
types of fuel it would provide one of the few viable means
of utilising these and similar products of fuel and
desulphurisation processes.
It was recognised that the heavy fuels with their higher
Conradson Carbon levels (Table 24) would very likely deposit
carbon on the bed at a higher rate as Conradson Carbon
relates well with carbon deposition during thermal cracking.
Tests were largely designed to study means of controlling
this within acceptable limits, air/fuel ratio, oxygen
enrichment and gasification temperature being examined. In
addition, a set of cycle tests were carried out with each
fuel.
Table 24
Comparison of Fuel Conradson Carbon Levels
Fuel Conradson Carbon (%wt)
Amuay Resid. 11.6
Amuay Vacuum Pipestill 17.4
Bottoms
High Sulphur Pitch 33.O
Amuay Vacuum Pipestill Bottoms used in fresh bed tests gave
the results shown in Figures 27 and 28. Operating conditions
for these tests are summarised in Table 25. Full details
are given in Appendix N.
- 109 -
-------
SRE'« DURING FRESH BED TESTS ON AMUAY VACUUM PIPESTILL BOTTOMS
100
8O
6O-
H
O
bl
*
0)
40-
X TEST 5-A (AMUAY BOTTOMS)
o TEST 5-B (AMUAY BOTTOMS)
A TEST 5-C (AMUAY BOTTOMS)
• TEST 5-0 (AMUAY RES 10.)
_L
_L
4 6
8ED SULPHUR CONTENT( WT.%)
6 10
Figure 27
-------
CARBON DEPOSITION ON BED DURING FRESH BED TESTS ON AMU AY VACUUM
PIPESTILL BOTTOMS
X TEST 5- A (AMUAY BOTTOMS)
O TEST 5- B {AMUAY BOTTOMS)
A TEST 5- C (AMUAY BOTTOMS)
• TEST 5-0 (AMUAY RESID.)
4 6
BED SULPHUR CONTENT (WT.%)
Figure 28
-------
Table 25
Condition* for Teete Plotted In Figures 27 and 28
Oxygen/Fuel Oxygen Gasification Superficial Initial Bed
Ratio InrichiMnt Temperature Oaa Velocity Depth
Te«t Svabol (% of itoich) t% exce«» 02) (*C) (rn/eec) Jem.) Fuel Limeatone
5-A X 23.0 O 8SS 1.77 39 Arauay BCR 1359
Bottoms
S-B O 26.7 25 91S 1.77 42
S-C A 28.1 25 945 1.95 43
5-D e 27.1 0 87O 1.86 38 Amuay
Res id.
In figure 27, SRE is plotted against bed sulphur content and
in Figure 28, the rate of carbon deposition is plotted
against bed sulphur content.
In Test 5-A the pipestill bottoms were studied under conditions
which had been found most suitable for the Amuay Resid., the
fuel which had been used to a large extent in the past. It
can be seen in Figure 27 that SRE dropped quicker with
increasing bed sulphur content than with the resid (Test 5-D).
The likely reason for this is indicated i'n Figure 28 where
the rate of carbon deposition on the bed was much higher with
the pipestill bottoms. In Test 5-B, therefore, conditions
were altered to reduce the rate of carbon deposition.
Gasification temperature was raised as this has previously
been shown to increase the rate of carbon burn-off in the
bed {Reference 1} and the fluidising air was enriched with
25% excess oxygen. These changes together with the increase
in oxygen/fuel ratio which accompanied them reduced the rate
of carbon deposition (Figure 28) and gave a consequent
improvement in SRE.
In order to achieve an even greater improvement and obtain a
result similar to that with the Amuay Resid., gasification
temperature was raised again whilst the same level of oxygen
enrichment was continued. Although these conditions had the
desired effect with regard to carbon deposition which was
reduced to a rate comparable with that obtained with Amuay
- 112 -
-------
Resid., (Figure 28) they gave lower SREs (figure 27). The
likely reason for this is that the increase in temperature
from 915 deg. C to 95O deg. C took the process outside its
optimum temperature range for this low rate of carbon
deposition (Reference 1).
In addition to these fresh bed tests, a series of 19 gasific-
ation/regeneration cycles was carried out. Conditions were
similar to those normally employed with Amuay Resid. i.e. an
air/fuel ratio of 27%, gasification temperature of 87O deg. C
and no oxygen enrichment. Details are given in Appendix N.
A lined out sulphur removal efficiency of 69% was obtained
which was similar to that which would have been predicted if
Amuay Resid., had been used under identical conditions. In
this case, the build up of carbon to a level where it inhibits
sulphur absorption did not take place as the carbon was
burned off during the regeneration stage of each cycle.
High Sulphur Pitch is a brittle solid at ambient temperatures
and needs to be heated to about 2OO deg. C for handling as
a liquid. At this temperature, however, it presents no
problems as far as pumping and introduction into the fluid
bed is concerned. Results obtained during fresh bed tests
with High Sulphur Pitch are shown in Figures 29 and 30.
Operating conditions for these tests are summarised in
Table 26. Full details are given in Appendix N.
Table 26
Conditions for Test* Plotted in Figure* 29 and 30
Air/Fuel Gasification Superficial Initial Bed
Ratio Temperature Gas Velocity Depth
Teat Symbol (I of atoich) (»C) (m/aec) (oa) Fuel Limestone
6-A X 24.5 395 1.72 45 High Sulphur
Pitch
6-B 0 31.6 885 1.76 45
5-D e 27.1 870 1.86 38 Arauay
Resid.
- 113 -
-------
SRE's DURING FRESH BED TESTS ON HIGH SULPHUR PITCH
IOO
80
60
UJ
oc
CO
20
• TEST 9-0 (AMUAY RES ID.)
X TEST 6-A (HIGH SULPHUR PITCH)
O TEST 6-B ( HIGH SULPHUR PITCH)
J_
JL
0
2
4 6
BED SULPHUR CONTENT(WT.%)
8
10
Figure 29
-------
CARBON DEPOSITION ON BED DURING FRESH BED TESTS ON HIGH SULPHUR PITCH
• TEST S-0 (AMUAY RESIO)
X TEST 6-A (HIGH SULPHUR PITCH)
O TEST 6-B (HIGH SULPHUR PITCH)
4 6
BED SULPHUR CONTENT( WT.%)
10
Figure 30
-------
In Figure 29, SRE is again plotted against bed sulphur
content and in Figure 30, the ratio of carbon deposition
against bed sulphur content.
As with the pipestill bottoms, SRE is related to the rate
of carbon deposition on the bed. At the higher rate of
carbon deposition of Test 6-A, SRE fell more rapidly than
at the lower rate of carbon deposition obtained at the
higher air/fuel ratio of Test 6-B. Also, as expected the
High Sulphur Pitch with its higher level of Conradson Carbon
exhibited a higher rate of carbon deposition then the pipe-
still bottoms under similar operating conditions.
Comparison of SREs obtained in the tests with the heavier
fuels shows that this is primarily dependent on stone carbon
and sulphur levels. Similar sulphur and carbon levels giving
similar SREs.
In addition to the fresh bed tests, a series of 20 gasification/
regeneration cycles was carried out. Details of the test
conditions which were similar to those normally employed are
given in Appendix N. The lined out SRE of 79% which was
obtained was similar to that expected from Amuay Resid.,
under similar conditions. As with the pipestill bottoms,
the build up of carbon to a level where it inhibits sulphur
absorption did not take place as the carbon was burned off
during the regeneration stage of eaoh cycle. In this case,
the average carbon content of the stone at the end of each
absorption test was 1.7% by weight.
The results on these two heavy fuels are considered to be
sufficiently encouraging to warrant further tests on heavy
fuels with steam injection to provide further information
on a means of controlling carbon deposition without adversely
affecting SRE. These tests should include a more detailed
investigation into the balance of gasification temperature
and steam injection required to give SREs comparable to
those which can be obtained with Amuay Resid.
- 116 -
-------
TASK III - SCOPING OF ENGINEERING EFFORT
The total development of CAFB through a 1OO+ MW demonstration
test period is expected to take about 6-^ years and require
$3,32O,OOO in engineering effort. Of this total, $570,OOO
is for developmental engineering and pilot plant guidance,
the remaining $2,750,000 is associated with the demonstration
project. Optimistically, the total development might be
accomplished in 4-fc years with $2,52O,OOO of engineering
effort. Conversely, greater costs and times could be
experienced.
The approximately 1 MW pilot plant at Abingdon can be scaled
to 10O+ MW without an intermediate pilot plant but with some
risk. To reduce the risk, large scale mock-up studies of
the fluidisation system and special engineering development
of critical equipment should be carried out. This scope
includes the engineering manpower for these studies but
does not include money to build any large scale test rigs.
These are assumed to be included in the laboratory programme.
The approach used in preparing this study was to assess the
state of development and the complexity of the process and
then determine a reasonable schedule to carry the develop-
ment to completion consistent with the criteria of
reasonable risk. Previous experience in process and project
developments similar to this was used as a guide. An estimate
was then made of the various types of engineering activities
required during the development and the extent of the effort
required for each activity. This estimate excludes
engineers who are directly associated on a full-time basis
with research activities or the operation of pilot plants
or demonstration plants.
The total programme has been divided into four activities,
and a "most probably" and an "optimistic" development
schedule has been estimated for each activity. Of course,
there is also the possibility of a longer and more costly
development programme if developmental problems prove
extensive or if significant modifications are required to
the demonstration plant due to start up difficulties.
The four activities in the development programme are:-
(1) Process Development
(2) Process Design
(3) Detailed Engineering, Procurement, Erection
(4) Startup and Test
- 117 -
-------
The engineering effort is summarised in Table 27. The costs
shown there are grouped to distinguish the engineering
guidance costs during pilot plant development work from the
engineering costs associated with design/ erection, startup,
and test of the large demonstration project. The project
work is divided into two categories; basic engineering and
the prime contractor's effort. Basic engineering includes
the basic process design, owner's interest protection and
follow-up during the detailed engineering and erection
stage, and the engineering associated with start-up and
testing. The prime contractor's effort involves the
engineering required for mechanical design and erection of
the demonstration plant.
In this schedule it was assumed that a client for the
demonstration plant would be obtained near the end of the
small scale development phase at which point a site would be
selected. Certainly the earlier the client is located, the
sooner it will be possible to direct both engineering and
pilot plant activities towards a specific project with
improved chances for shortening the time and cost of the
development work.
The schedule and cost of the development activity is a major
uncertainty in this type of effort. The schedule depends
to a large extent on the degree of effort expended and the
degree of risk which might be considered acceptable when
starting the demonstration plant design. The estimate of
18 months for additional small scale development assumes
minimum future pilot plant problems, very little process
optimisation, and a higher risk in proceeding with the
demonstration plant than if more extensive (experimentation
and engineering) development work were undertaken.
- 118 -
-------
Table 27
CAFB Development Programme
Summary of Engineering Effort
(1)
DEVELOPMENT
Most Likely
Optimistic
Ik
570
Dates
1/73-7/75
|k
360
Dates
1/73-7/74
PROJECT
Basic Engineering
- Process Design
- Owners Interests
- Startup and Test
420
580
550
10/74-10/75
10/75-7/77
7/77-4/79
270
390
5OO
1/74-8/74
6/74-9/75
9/75-4/77
1,550
17160
Contractors Design
and Erection
1,200 10/75-7/77 1,OOO 6/74-9/75
3,320
(1) Cost of Engineering work only - costs of experimentation,
pilot plant work, construction, and demonstration plant
operation are excluded.
- 119 -
-------
SECTION VII
REFERENCES
1. Study of Chemically Active Fluid Bed Gasifier for
Reduction of Sulphur Oxide Emissions. Final Report,
OAP Contract CPA 70-46, Esso Research Centre, Abingdon,
Berkshire, June, 1972.
2. Curran, G.P., Fink, C.E. and E. Gorin.
Phase II Bench-Scale Research on CSG Process, R&D
Report No. 16. Report to Office of Coal Research,
Contract No. 14-01-OO01-415, Consolidation Coal Co.
July 1st, 1969.
- 120 -
-------
SECTION VIII
INVENTIONS
1. UK 50014/72 Moss, Craig, Taylor and Tisdall
Preventing agglomeration during regeneration of
sulphides by passing stone from the gasifier into a
region of the regenerator which is separated by a
layer of fluidised stone from the regenerator
distributor.
2. UK 24739/72 G. Moss
Production of a highly sulphated lime from CAFB
regenerator off-gas, to avoid the need for reduction
of S02 to sulphur or production of sulphuric acid.
3. UK 29513/72 Moss and Taylor
Reduction of attrition in fluidised beds by a two stage
nozzle, the first stage being a high pressure drop
orifice, and the second stage providing dissipation of
kinetic energy and a non-attriting gas velocity into
the fluid bed.
- 121 -
-------
TERMINOLOGY
Sulphur Differential
Superficial Velocity -
Fluidised Bed Depth
(cm)
Lime Replacement
Sulphur Removal
Efficiency (SRE)
Calcination
Adiabatic
Gasification
SECTION IX •
GLOSSARY
The difference in total sulphur
level on the fluid bed between start
and finish of a batch gasification
run, or between the inlet and out-
let streams from gasifier to
regenerator in a continuous unit.
The velocity of the fluidising
gases (air plus flue gas recycle,
but excluding gas and vapour formed
from the fuel) in the empty gasifier
or regenerator bed, at the temper-
ature of the bed.
(Fluid head from above distributor
to gas space above the bed)
* (Fluid head per cm of bed)
Fresh limestone added to the
gasifier, expressed as weights of
CaO -in the limestone added over a
given period per unit weight of
sulphur in the fuel gasified during
the same period. Alternatively
expressed as a ratio of moles CaO
added per mole S in the fuel gasified,
(, SO., observed in flue gas)
— / J»~ » v
( S02 if none absorbed
)
xlOO%
Removal of C02 from limestone by
heating above approximately
750 deg.C.
Operation at low air to fuel ratios
in the gasifier such that heat
released by partial oxidation of
the fuel just serves to maintain
the gasifier temperature at the
required level. (Air supply about
14% of that needed to fully
combust the fuel) .
- 122 -
-------
Combustion
Megawatt (MW)
Operation at high excess air levels
during combustion in the gasifier
such that the gasifier temperature
just remains at the required level
(Air supply about 4OO% of that
needed to fully combust the fuel).
Used in this report only for
electrical power generation rate.
SYMBOLS USED IN TEXT
A Bed age in hours (batch tests)
D Bed Depth (cm)
d Particle size, microns
dav Surface area mean particle size/ microns
L Loss rate from bed, g/min
S Bed Sulphur Content (total), weight %
T Bed temperature, deg.C.
W Weight of fraction in sieve analysis
V Micron (1O~6 metre.)
- 123 -
-------
SECTION X
APPENDICES
- 124 -
-------
APPENDIX A
STARTUP AND OPERATIONAL PROBLEMS
NATURE OF STARTUP PROBLEMS
During start up of the continuous pilot plant in Run 4,
problems were encountered in the following areas:-
(a) Blockage in solids transfer line
(b) Plugging in regenerator gas outlet system
(c) Dust emissions to boiler from gasifier
(d) Dust in flue gas recycle stream
(e) Dust emissions to atmosphere
(f) Regenerator Agglomerates
All of the problems were related to differences in the
characteristics of stone BCR 1691 from those of the
Denbighshire stone used in the continuous unit during Phase I
studies (Reference 1). The major differences are lower fusion
temperature, the cause of problems (a) and (f) above and
production of a higher proportion of very fine dust in a
fluidised bad under fully combusting conditions, the cause
of problems {b) through (e). The dust produced from BCR 1691
is more difficult to retain in collection equipment than that
originating from Denbighshire stone. It also clings to
surfaces of pipes, cyclones, control valves etc, and is
difficult to dislodge without application of direct mechanical
force. It does not drain from hoppers, or even vertical
pipes, without continuous rapping.
Transfer Line Blockage
Heatup of the pilot plant for Run 4 started on July 28.
Stone addition was begun the afternoon of August 1, and by
early on Aug 2, a hot fluidised lime bed was established
under kerosene combustion conditions. However, efforts to
establish good solids circulation through gasifier and
regenerator were unsuccessful. Attempts to rod out the
transfer lines did not improve circulation very much. The
unit therefore was shutdown on August 4, allowed to cool and
opened for inspection on August 8. The blockage was found to
- 125 -
-------
consist of a fused mass of lime particles which obstructed
most of the mixing pocket in the regenerator to gasifier
(R to G) transfer line. The transfer line from this mixing
pocket to the gasifier also contained a quantity of material
with the appearance of foamed slag.
Reconstruction of the startup procedure indicated that the
obstruction was caused by limestone particles and fines
entering the R to G transfer line during the initial stages
of stone addition while the pocket and transfer line were
heated by direct gas flame. The geometry of the system is
now such that stone enters the bed from the stone feeder at
a point directly opposite the R to G line. The start up
burner is between the stone feed point and the R to G line.
During start up, gasifier pressure had been maintained well
above regenerator pressure to drive hot gas into the
regenerator to raise its temperature. It is evident now
that flame had actually entered the transfer line along with
stone. The silica content of the BCR 1691 stone lowers its
melting point enough to allow fusion under these conditions,
producing, in effect, flame spraying of fused stone directly
into the R to G transfer line.
The solution to this problem is to adjust pressure balance
during the early stages of stone addition to avoid overheating
the R to G transfer system. This method was adopted for the
second start up. As added precautions, a thermocouple was
installed in the transfer pocket, and low silica Denbighshire
stone was added initially to form a bed deep enough to cover
the transfer line. The experience gained during the second
bed addition on 15 August indicates that flow of hot gas and
stone into the R to G line can be prevented by adjusting the
pressure balance and that no trouble would have been
experienced with the 1691 stone alone. The thermocouple in
the transfer pocket is a valuable guide to temperature and
flow conditions at that point, and its continued use is
recommended. No blockage was encountered during the second
stone addition, and once good fluidisation and combustion
were established, high circulation rates between beds were
easily obtained. Some difficulty was encountered in
establishing initial fluidisation with 30O to 32OO micron
stone. Indeed each startup had encountered some trouble
during the initial period of stone addition because of the
high heat load required for stone calcination and the high
gas velocity required to fluidise uncalcined stone. In this
startup, good fluidisation and operating bed temperature were
achieved after addition of some precalcined stone removed
from the unit in Run 3. Use of calcined lime is recommended
for startup in future runs.
- 126 -
-------
Regenerator Gas Outlet System
During the startup period of Run 4, dust in the regenerator
off gas stream continually blocked the regenerator cyclones
and the gas exit line and control valve down stream of the
cyclone. It was possible to keep the cyclone functioning
only by continuously rapping on its body. Without this
rapping, solids failed to drain, quickly filled the cyclone
interior, and went overhead to form restrictions further
down stream. It was found that the overhead line remained
relatively clean in straight sections and smooth bends but
plugged at sharp bends and fittings.
The character of regenerator fines changed when gasification
began on August 20. Almost immediately the regenerator
cyclone became free draining and operative without rapping.
The colour of the fines also changed to a darker hue. Micro-
scopic examination showed the dust from the combustion period
to have a high proportion of very fine particles. Figures
1 and 2 are photomicrographs of regenerator solids obtained
under combusting conditions (1) and gasifying conditions (2).
The larger particle size and reduced agglomeration tendency
of the gasifying samples is apparent.
Nevertheless, the regenerator outlet control valve eventually
plugged after nine hours of gasification and the run was
terminated. Inspection of the outlet system revealed no
accumulation of fines except at the valve itself. The solids
forming the plug appeared to be more like those formed during
combustion than during gasification, and it is possible that
they were a remnant of the pregasification period which had
dislodged from the transfer line and moved down stream to the
valve.
Dust Emissions to Boiler
A large quantity of dust passed from the gasifier into the
boiler. Much was retained within the boiler, particularly
at the back end of the main fire tube, where the flue gases
change direction abruptly through 180 degrees, but some
passed through to be caught in the external cyclone or to
escape from the stack. There are indications that fines
losses decreased during gasification, but the period was too
short to confirm this observation.
- 127 -
-------
Fig, 1 Photomicrograph of Regenerator Fines
under Combusting Conditions.
Fig. 2 Photomicrograph of Regenerator Fines
under Gasifying Conditions.
- 128 -
-------
Unlike previous operations where fines also entered the
boiler, this time we were unsuccessful in withdrawing
solids from the drain points at the boiler end. The solids
failed to drain because of their steep angle of repose.
A contributing factor to high losses from the gasifier was
the greater bed pressure drop used in the current run. In
earlier runs/ a maximum bed pressure drop of 4.73 kPa
(19 inches water gauge) was used. In the current run this
was increased to 6.47 kPa (26 in. w.g.).
This increase in pressure drop together with a reduced
density of fluidised cyclone fines (due to lower average
particle size) caused level of solids in the cyclone drain
line to reach the cyclone itself and decrease cyclone
efficiency.
Dust in Flue Gas Recycle
Two stages of cyclones in the flue gas recycle system failed
to remove fines to a degree which would assure long term
cleanliness of the gasifier distributor. No pressure drop
increase in the distributor was observed during the short
test period, but fines observed in the flue gas sample line
filter {downstream of the cyclones) indicated that a problem
eventually would have occurred.
External Dust Emissions
The external settling chamber and cyclone which proved
adequate for final flue gas clean up in Run 3 was unable to
cope with the fine dust produced under combustion conditions
in the current run.
In part, poor performance of the external cyclone was also
caused by the sticky nature of the fines. The interior of
the cyclone was quickly coated with a layer of solids which
impaired its efficiency.
Regenerator Agglomerates
Analysis of Run 4 temperature records and inspection of
samples retrieved from the regenerator revealed an additional
problem with BCR 1691 stone. During the early portion of the
Run 4 gasification period, an upset in pressure balance
interrupted solids circulation and allowed a brief temperature
excursion. The temperature in the lower portion of the bed
- 129 -
-------
reached 1130 deg. C. After this upset, the temperatures in
the upper and lower regions diverged with the lower
temperature logging about 8O deg. C below the upper one.
This condition indicates poor fluidisation. When the
regenerator was opened for Inspection a number of agglomerates
were found. We believe that these lumps formed during the
brief high temperature period in spite of bed fluidisation.
In previous runs with Denbighshire stone there had been
temperatures of over 1130 deg. C without encountering
similar losses in fluidisation. This difference in behaviour
is attributed to the lower fusion point of the lower purity
BCR 1691 stone.
- 130 -
-------
APPENDIX A - TABLE I
Particle Size Analysis Run 4
Sample Location
Solids from Regenerator
Gasifier Regenerator Boiler Cyclone Fines
Bed Bed Fire Tube (gasification)
Particle Size,
wt % in Fraction
140O
140O
1180
850
600
355
25O
150
106
Bulk
Micron +
- 1180
- 850
- 6OO
- 355
- 250
- 150
- 106
- Dust
Density g/cc
39
11
22
15
11
0
0
0
0
1
.8
.5
.2
.3
.0
.5
.2
.1
.5
.13
21
8
18
13
14
5
12
0
3
1
.6
.8
.0
.9
.7
.8
.7
.8
.7
.08
19
6
13
13
20
7
5
2
13
.3
.3
.O
.0
.5
.1
.1
.8
.0
.85
.27
)
) .27
)
.27
.27
10.
11.
76.
1.
*
*
*
*
6
4
9
03
* These particles had a white appearance,
distinctly different from that of the
finer particles.
- 131 -
-------
APPENDIX A - TABLE II
u>
Regenerator
Gasifier (During
Units (After Shutdown) Gasification)
CaO %rt%
MgO «
A1203
S±O2
Fe
Da •
v «
CO2
S (total)
S as sulphate *
Loss on Ignition *
Gain on Ignition "
SiO2/CaO
MgO/CaO
Al203/CaO
SiO2/C«O In Original Limestone
MgO/CaO " «
Al2O3/CaO •
53.9
3.95
2.35
22.1
0.73
0.06
0.13
1.84
4.88
4.39
-
0.21
O.41
O.O74
O.O43
58.8
4.7
3.0
24.1
0.87
O.O7
0.15
0.73
2.09
2.06
-
O.16
O.41
0.080
0.051
0.27
0.074
O.O46
Boiler
(After
Shutdown)
57.0
4.35
2.85
18.6
1.02
O.07
0.11
0.36
1.56
1.28
7.46
-
0.33
O.O76
O.050
Regenerator
(During
Combustion)
68.1
4.1
4.1
21.2
0.97
0.06
0.04
0.21
0.74
0.72
0.31
_
0.31
O.O6O
O.O6O
Cyclone Fines
(During
Gasification)
59.9
4.2
3.6
21.6
0.87
0.08
0.38
O.12
5.51
2.58
4.09
O.36
0.070
O.O6O
-------
APPENDIX B
RUN 5
Operational Log, Inspection, and Data
Page
Operational Log 134
Inspection and Figures 1-14 148
Data Table I Temperatures and feed rates 163
II Gas flow rates 172
III Pressures 181
IV Desulphurisation Performance 190
V Gas Compositions 2OO
VI Sulphur and Stone Cumulative 212
Balance
VII Analysis of solids, Total 223
Sulphur
VIII Analysis of solids, Sulphate 224
Sulphur
IX Analysis of solids, Total 225
Carbon
X Analysis of Solids, V, Na, Ni 226
XI " " " CaO, SiO2 227
XII " " " Sieve 228
Analysis
XIII " " " " " 229
XIV " " " Ignition 23O
loss
XV Solids withdrawn 231
Figures 15 237
16 240
- 133 -
-------
APPENDIX B
CAFB RUN 5
OPERATIONAL LOG
2.2.73 to 6.2.73 (Unit warm up)
The warming up procedure started at O4.3O continuing at
a steady rate with the propane burner. At 11.3O on 5.2.73
the temperature was sufficiently high to introduce kerosene
using the three metering pumps. At 17.30 hours Denbighshire
limestone was fed to the unit with the fuel rates adjusted to
maintain an adequate bed temperature rise. Bed circulation
and fluidisation was good.
6.2.73 (Day 1 of Gasification)
Preparations were made for gasification and at 15.OO the
boiler door was shut and check out of the flue gas recycle
system completed and gasification commenced. Soon after the
start of gasification there was a series of automatic plant
shut downs caused by a combination of boiler low pressure
alarm actuation and cooling water high temperature alarms.
Both these safety features are automatic in their operation
and complete plant shut down cannot be overridden in these
circumstances. The shut downs were started by the boiler
water outlet temperature which began to climb from its normal
level of 100°C to the alarm level of 12O°C whilst maintaining
a constant boiler water inlet temperature suggesting a fall
off in water flow to the boiler. This situation had been
seen briefly on Run 4 and instrumentation had been added to
the pump on the boiler cooling water to monitor pump perfor-
mance. At this period the pump discharge pressure had fallen,
possibly due to an air lock in the pump suction line which
was then bled releasing a considerable quantity of air from
the line.
At the same time adjustments were made to the burner air
distribution because observations had shown a very short
intense flame in the boiler which could have caused some
local boiling in the boiler. Either one or both of these
actions re-established good water circulation which in turn
cooled the boiler system sharply and the pressurisation unit
pumps were unable to cope with the make up water required to
maintain pressure and the low water pressure alarm operated
and the plant shut down. Then followed a series of problems
- 134 -
-------
in which the pressurisation unit was unable to maintain
pressure within its operating band and when the automatic
cooling control valve cut in, the pressure dropped towards
the low pressure shut down condition. Attempts to assist
this transient by cutting the secondary side cooling pump
slowed down the cooling rate but permitted local convection
circuits to activate a high temperature alarm and shut down
the plant again. After a series of shut downs due to either
low pressure or high temperature, the control system on the
pressurisation unit was reset with a wider operating band
and some remaining air bled from the boiler circuit and this
established a workable control system. At 20.45 gasification
restarted and the unit settled out and gradually the regener-
ator came up to operating temperature by manual control of
bed circulation.
7.2.73 (Day 2)
There was some difficulty in getting the regenerator temper-
ature up to 1O5O°C and the gasifier temperature was increased
to 950*C to help this problem. It was then apparent that bed
transfer between gasifier and regenerator was improving and
control was transferred to the automatic controller. The
gasifier temperature was lowered to 87O°C without any problems
with the regenerator which was operating with an 8% S(>2 stream.
At 14.45 conditions were lined up for the first data point
but steady regenerator conditions were now difficult to hold
and at intervals the automatic temperature controller was
unable to properly regulate the flow of material and high
temperatures resulted in the regenerator.
The venturi scrubber drain on the flue gas recycle line
became blocked and flooded the blower with water and the
drain was rodded out to clear away the accumulation of
caked lime dust which had been washed out in the scrubber.
8.2.73 (Day 3)
The regenerator to gasifier transfer line was partially
blocked but was rodded out with some improvement in material
transfer. The pressures on the transfer line nitrogen pulsers
were reduced to investigate their effect upon bed transfer.
At 15.15 bed material and dust samples were taken.
At 2O.3O all the analytical equipment was checked and a water
knock out pot placed in front of the boiler sample line cotton
wool filter to reduce the water carried to this filter. At
23.3O further bed material and dust samples were collected.
- 135 -
-------
The stone feed was temporarily stopped to determine the
material loss rate and after 3 hours there was no appreciable
change in either of the two bed levels.
9.2.73 (Day 4)
Fluctuations in the boiler burner throat temperature were
observed which seemed to correspond with the operation of the
fines return transfer system. The nitrogen pressure setting
on the left hand vessel aerator .was reduced to try and
minimise the effect of these residual gas pulses which could
pass up the cyclone drain after each operation of the fines
transfer system. This action was almost immediately followed
by a blockage in the transfer system which was subsequently
cleared by raising the pressure back to its original value
and knocking the pipe to encourage transfer.
Prior to adding BCR 1691 limestone the bed was lowered by
draining 68 kgs (ISO Ibs) from the regenerator. It was
observed that during this period with a low gasifier bed
level the gasifier space pressure increased more sharply
and this may have been because less material was thrown into
the cyclones to scour the deposits.
At 04.55 BCR 1691 stone feed was started to build up the bed
back to 64 cms (25 ins). The main air compressor on the site
service supply developed a faulty valve which let most of
the supply bleed to atmosphere and reduced the unit supply
pressure to such an extent that the pneumatic controllers
and rappers all started to malfunction. The fault was temp-
orarily rectified and the unit then left to steady out after
these disturbances.
The regenerator performance was not very good and at 08.3O
the control temperature was lowered to encourage more
circulation and hopefully better regeneration.
The limestone feed rate of 27 kgs/h (59.4 Ibs/h) which was
used to build up the bed height produced a larger quantity
of material in the cyclone transfer system and also produced
more problems in obstructions in the feed line to the
elutriator.
At 15.OO three boiler gas samples was taken and gave
110 cms3/m3f 108 cms3/m3 and 101 cms3/m3 NOX by the chemi-
luminescene method of analysis. During the afternoon
trouble was experienced with the main flame failure alarm
which repeatedly cut in but all other instruments were
- 136 -
-------
normal and it was assumed to be an electrial fault or dust
masking the flame eye vision. The boiler sampling line
became blocked in the boiler door and after cleaning this
obstruction the jrfostoff analyser showed higher SC>2 levels in
the boiler.
At 23.30 some problems arose when the scrubber water separa-
tor drain blocked again and water was carried through the
recycle blower and some reached the gasifier plenum from
which water dripped for the following few hours.
10.2.73 (Day 5)
Some flame outs of the main flame pilot were encountered and
the trouble was found to be caused by a blockage in the
sighting tube for the pilot eye which was rodded out and this
cleared the problem.
At O1.3O a sudden upward jump in the gasifier temperature
accompanied by a drop in the pump delivery pressure showed
that the fuel supply had run out due to some misunderstood
directions about the supply situation. After some initial
problems in reestablishing the oil supply the main flame was
lit and the unit allowed to line out.
The gasifier bed density manometer showed a gradual lowering
of the bed density during the proceeding hours of gasification
suggesting the cyclones were retaining and the system return-
ing a large proportion of the generated fines. At 08.15
the elutriator nitrogen rate was increased to remove some
more fines because of the continued decrease in the bed
density. The regenerator performance of 4-5% S02 was still
well below previous results when values up to 10% were
achieved.
Bed material and dust samples were taken at 10.45 before
changing from this data point condition to one where the stone
feed was reduced to about 15 kgs/h (33 Ibs/h).
At 10.30 the boiler flue gas temperature began to rise at
about 1°C per hour. About this period there were problems with
an obstructed pressure tapping in the regenerator bed depth
measurement and whilst this was drilled out the regenerator
bed temperature rose to IIOO'C but was prevented from going
higher.by the nitrogen quench system which had been installed
for this overtemperature situation. These two problems
were interlinked because when the bottom tapping blocked the
bed height and hence the air rate could have changed so
- 137 -
-------
upsetting the balance of material flow and temperature too
sharply for the automatic controller to follow.
At 17.00 the pneumatic controller on the left hand cyclone
drain system stopped working because of some very fine dust
which had passed through the filter and the purge in the
pressure tapping on the vessel finally getting into the
miniature control valve. This valve was removed and cleaned
whilst a fine filter and longer purge line were installed.
The systems were reconnected by midnight and normal stone
feed resumed to re-establish conditions.
11.2.73 (Day 6)
The gasifier bed depth of 63. cms (24.6 ins) did not throw up
much material into the cyclones and S02 in the boiler grad-
ually decreased when the gasifier bed depth increased. The
regenerator cyclone rapper stopped for a period and during
this time there was some laydown of fines in the system
because when the rapper was restarted the regenerator back-
pressure suddenly decreased suggesting the removal of some
blockage.
At O7.3O samples were taken of bed material and dust from
the various collection points. The pressure in the gasifier
space had reached 6.7 kPa (27 ins wg) due to carbon deposited
in the cyclones and ducts which was removed by the standard
operation of bed sulphation and a burn out procedure. At
10.30 the bed sulphation commenced and by 11.05 the process
was complete. This was followed by burning out the carbon
in the cyclones and ducts using the recycle system with a
controlled oxygen content so keeping the duct temperatures
below 120p°C. After the burn out was completed the unit
was put onto combusting conditions with kerosene and main-
tenance completed on the venturi scrubber which was obstructed
in the throat with lime deposits. The bed circulation under
these combusting conditions was very bad and difficulty was
experienced in getting material into the regenerator. The
high regenerator distributor pressure drop suggested some
obstruction in this area - possibly a fused lump on top of
the distributor which was preventing fluidisation of the
material. Troubles was also found with both the pneumatic
control systems on the fines return from the cyclones. It
was decided to shut down the plant temporarily to remove
the distributor in the regenerator.
- 138 -
-------
12.2.73 (Day 7)
The distributor was removed but the bore of the regenerator
was completely clear. There was some obstruction in a few of
the distributor holes which could have accounted for the
high pressure drop. The gasifier to regenerator transfer
line horizontal leg was rodded out and the distributor was
replaced but bed circulation was still bad and all attempts
at rodding, pressure adjustments and changing pulse settings
did not improve matters significantly.
13.2.73 (Day 8)
Gradually bed transfer improved as the bed depth increased
in the gasifier and the problems with the fines pneumatic
control system were resolved. At 12.5O the boiler was
cleaned out prior to preparation for gasification and at
19.2O gasification was restarted.
14.2.73 (Day 9)
The regenerator fluidisation was not satisfactory because
below 1.22 m/s (4 ft/sec) the bed temperature at the bottom
of the bed dropped sharply. The irregular behaviour of the
regenerator bed temperature control thermocouple made auto-
matic control very unreliable and manual control was resumed.
At 04.30 the regenerator defluidised with the bottom temper-
ature dropping 2OO°C and the upper temperature exceeded
11OO°C. Further attempts at achieving good bed transfer
were unreliable and once again the regenerator defluidised
with a high top temperature excursion. At 05.35 the unit
was sulphated and the ducts burnt out because continued
operation could have produced a fused lump in the regenerator
with repeated defluidisations and high temperatures.
The unit was set back on combusting conditions so that the
problem associated with the regenerator and erratic fines
transfer could be solved. The fines return system was
stripped out and flakes of carbon and lime which were released
into the system after the burn out were found obstructing the
transfer lines. The right hand cyclone drain vessel was
removed to permit access to the gasifier to regenerator
transfer line drain plug. The regenerator distributor was
removed and replaced with a temporary insulated mild steel pad
inserted so that the unit could be restarted under combusting
conditions whilst the distributor was investigated. The
regenerator bore was obstructed with a considerable deposit
of agglomerated material in the lower section.
- 139 ^
-------
15.2.73 (Day 10)
Further work was carried out on the fines control system and
automatic feed of the fines back to the gasifier to free all
obstructed areas and the system was reinstalled satisfactorily.
The gasifier lower pressure tapping blocked and was drilled
out. Examination of the regenerator distributor showed that
the raised lip of refractory around the nozzles had broken
away in one area and this was repaired by building up with
refractory cement and refitted into the unit. Further trials
on bed transfer were not very successful and persisting
problems were encountered with the gasifier lower tapping
which continued to plug up. Eventually the lower tapping was
removed and replaced with a new one, having become totally
obstructed with solids. The bed transfer lines were rodded
to encourage circulation and after draining some material
from the regenerator distributor drain, the flow rate improved
and by 21.30 circulation was quite reasonable.
16.2.73 (Day 11)
The boiler was cleaned after the period of combusting cond-
itions, door resealed and made ready for gasification.
Further trouble was encountered with the fines return system
becoming obstructed with flaky material which continued to
fall from the cyclones. These flakes could only be removed
by dismantling the transfer pipe from the pressure vessel
and the cone feed control at the gasifier feedpoint.
At 12.15 gasification was restarted with some difficulties
occurring in the fines transfer due to carbon-lime flakes
which continued to drop from the cyclones. The scrubber
also blocked at its entry point but was cleared by hammering
the pipework. A stainless steel screen was fitted into the
fines return line to the gasifier to arrest the carbon flakes
before they obstructed the control valve.
17.2.73 (Day 12)
The regenerator continued to act in an erratic manner with
uncontrolled temperature excursions to 1100'C and there were
many periods of poor fines transfer mainly due to flakes
falling from the cyclones. Some of the problems of poor fines
return were eliminated by adjusting the outlet ball valve seats
which had become worn and were not gastight. At 16.OO the
unit was reasonably steady and conditions were held for 2
hours so that a set of samples could be taken at the beginning
and end of the data period. After this was completed, the
- 140 -
-------
gasifier bed depth was reduced in preparation for the next
data point. The boiler probe controller malfunctioned and
permitted the temperatures of the probe to rise well above
the 6OO°C control point.
18.2.73 (Day 13)
At 04.00 and O6.OO sets of bed material and dust samples were
taken. The gasmeter measuring the nitrogen for the gasifier
to regenerator transfer system was found to be leaking and
was replaced.
The boiler SO2 level appeared to be sensitive to regenerator
performance and efforts were made to maximise the SO2 output
from the regenerator thus giving minimum boiler SO2 levels.
The gasifier pressure had gradually risen and at O9.OO there
was gas leaking from the gasifier lid and a sulphation and
burn out was necessary. Some of the bed material was removed
before this procedure and by 12.30 the operation was completed.
There was a fuel leakage from the unit showing as a distillate
dripping out of the bottom with distillate fumes coming out
of the top around the lid. A pressure check on the shell
space showed that the inner refractory concrete was not with-
standing any differential pressure which was contained by the
steel casing.
The gasifier bed temperatures showed a spread of 10O°C suggest-
ing poor fluidisation and a possible contributory factor to
the apparent incomplete fuel combustion. A bed sample was
sieve analysed and 74% of the bed material was above 1400
microns showing that there could be fluidisation problems.
This was supported by the poor regenerator bed behaviour.
19.2.73 (Day 14)
The fuel injectors were all rodded through but without much
change in the unit behaviour. Some BCR 1691 bed material
with 4O% of the particles above 140O microns was fed to the
unit to lower the average particle size and at O9.3O a bed
sieve analysis showed 51% of the bed was above 14OO microns.
Further redding of No. 3 fuel injector with a high pressure
nitrogen lance cleared an obstruction at the discharge end of
the injector. The gasifier bed was slumped and the injector
withdrawn whilst a purge of nitrogen was arranged to prevent
the outflow of volatile product which was still leaking from
this area. The end of the injector had burnt away leaving
- 141 -
-------
an unrestricted flow giving a very poor spray pattern and
bad combustion conditions so permitting unburnt fuel to leak
into and crack in the hot zones. The vapour passed up the
expansion gaps around the gasifier refractory to emerge
around the top of the unit with the remaining product leaking
from the bottom of the gasifier.
20.2.73 (Day 15)
Attempts were made to break up any lumps in the bed by rodding
out with stainless steel high pressure nitrogen lances through
various access points. A temperature traverse was made
through the bed above the distributor to investigate quality
of fluidisation which looked reasonable. The permanent low
value of the bottom bed thermocouple may have arisen from a
build up of material around the couple shielding it from the
correct bed temperature.
The remaining two fuel injectors were withdrawn and although
apparently undamaged/ new ones were fitted to eliminate any
further difficulties from this source.
The gasifier bed fluidisation improved after this work and
the unit was brought back to temperature and circulation
checked out. At 21.3O the boiler was cleaned out and
preparations were made to start gasification.
21.2.73 (Day 16)
Some problems were encountered with the regenerator, gasifier
and fines return pressure tappings which had become blocked
with fine dust during the long period of combustion
conditions. There were additional problems with the butterfly
valves on the cyclone drains which did not shut off tightly
without manual assistance.
Gasification was restarted at O6.OO and at 1O.OO the boiler
SC>2 level was about 5OO ppm and the regenerator output about
3% SO2. The carbon flakes continued to occassionally block
the cyclone fines return system and the scrubber became
fouled again with lime deposits.
At 20.30 there was a main flame failure alarm which reset but
during the following hour this recurred six times. The fuel
oil supply tank was switched in case of starvation and the
problem did not reappear.
- 142 -
-------
The fines return to the gasifier was erratic and could not
match the supply rate so that some of the material was
externally drained and fed back into the unit with the stone
feedstock while the problem was resolved.
22.2.73 (Day 17)
The right hand cyclone was erratic in its material return
mainly caused by the coarseness of the material which does
not move as well as fine material in this type of transfer
system. Samples of bed material and dust were collected at
11.3O after a period of fairly steady operation.
Pneumatic delay valves was fitted to the operators of the
cyclone fines outlet valves to ensure that they shut off
after the opening of the butterfly valves at the foot of the
cyclones. This prevented the partial depressurisations of
the transfer vessel into the cyclone drain leg so releasing
dust into the boiler. The perforated plate which was inserted
into the cyclone fines return to the gasifier reduced the
material flow rate back to the gasifier and was replaced by
one with a larger open area to prevent the material building
up in the system. Samples were taken of bed material and
dust at 18.OO.
The regenerator fluidisation was erratic with temperatures
spread by 50°C but the situation was improved by periodic
draining of material suggesting a build up of coarser particles
which were close to defluidisation. During this period there
were problems with the regenerator air rate which showed some
supply limitation and coupled with the bad circulation of bed
material, regenerator temperature control was very difficult.
About 22.00 the regenerator temperature rose to almost 11OO°C
coupled with apparent defluidisation and it was necessary to
sulphate the bed and burn out the ducts to prevent the form-
ation of a solid plug in the regenerator.
23.2.73 (Day 18)
The bed sulphation and duct burn out was completed by 01.00
and the unit was put into combusting conditions. The bed
level was lowered by removing 98 kgs (216 Ibs) of bed material
and preparing to feed Denbighshire limestone. The regenerator
and gasifier beds were sampled and sieve analysis showed 75%
and 68% respectively of material above 1400 microns indicating
a large average particle size in the unit. The regenerator
distributor was removed again to check the erratic
performance but the bore was generally clean with only small
- 143 -
-------
areas of deposits on the joint between the distributor and
the wall and some deposits between the nozzles. The cracks
in the bore of the regenerator concrete were not obviously
worse than before the run started but repairs were made to
the lower section cracks using Sairset cement to prevent air
bypassing the fluid bed.
24.2.73 (Day 19)
The regenerator distributor was repaired in those areas of
the sealing face where the material had cracked away and the
assembly installed with a soft high temperature insulation
layer to act as a sealing gasket onto the refractory. The
problems of achieving a good seal on this face during re-
assembly were not helped by the high temperatures in the
area. The transfer lines to and from the regenerator were
rodded without meeting any obvious obstruction.
Fresh bed had not been added during the previous 15 hours and
a sieve analysis of a gasifier lower bed sample showed that
47% of the material was greater than 1400 microns which was a
fairly typical value from previous experience. This size
range of material should have fluidised easily and did not
explain the continual difficulties in obtaining good regener-
ator fluidisation and transfer to and from the regenerator.
25.2.73 (Day 20)
Better regenerator fluidisation was obtained by draining out
a quantity of the bed and allowing it to refill with hot stone
which increased the actual gas velocity in the bed without
increasing the flow and pressure drop through the distributor.
At O8.45 regenerator transfer and fines return systems were
both working well and preparations were made to start gasific-
ation by checking out instruments, cleaning drain lines and
sample lines. At 18.OO gasification started without problems
and conditions left to stabilise.
26.2.73 (Day 21)
The main feature of this data point was the high fuel rate of
215 kgs/h (474 Ibs/h) with the minimum flue gas recycle rate.
It was not possible to get to adiabatic conditions but the
flue gas was reduced to 68 m3/n (4O ft3/m) with a superficial
velocity in the gasifier about 1.35 m/sec (4.1 ft/sec.). Bed
material and dust samples were taken at O7.OO.
- 144 -
-------
The interaction between the cyclone fines return into the
gasifier and the boiler S02 concentration was observed again -
adjustment was made to the transfer system pressure levels to
reduce the gas leakage and blow back up the cyclone drain leg
at each cycle operation. When the fines were diverted from
returning into the gasifier bed, the boiler SC>2 level steadied
indicating that the irregularities in the boiler S02 were
caused by the fines injection. At 18.OO a further set of
samples was taken and sieve analysis on two samples from the
gasifier bed showed 36% and 30% above 14OO microns at 20.05
and 19.30 respectively.
27.2.73 (Day 22)
The unit ran steadily with the main problems occurring in the
fines return transfer vessel operation. A set of samples was
taken at O7.15 and gas samples were collected from the
gasifier at 10.30.
The cyclone drains appeared to be partly obstructed because
there was not very much material transferred at each operating
cycle and the boiler dust collection systems were picking up
more material than usual. The regenerator transfer system was
erratic causing problems with temperature control, but the
situation was improved by rodding out the lines with a nitrogen
lance. A further set of samples was collected at 17.3O
including two gas samples.
The gasifier space pressure had gradually built up to 7.O kPa
(28 ins w.g) and a sulphation and burn out was started at
19.OO. After completion of this procedure the unit was set
on combusting conditions with kerosine so that checks would be
made on various systems before resuming gasification.
29.2.73 (Day 23)
The cyclone drain systems were apparently blocked because
there was hardly any delivery of material to the elutriator.
The valves above the cyclone outlets were used to pass a long
nitrogen lance through to the cyclone drain legs and this
displaced some lumps and finer material. After some further
rodding of transfer lines the bed circulation was reasonable
and preparations were made for gasification which was resumed
at 13.OO after boiler cleaning. Soon after gasification
started, lumps of material were still falling from the cyclones
and obstructing the transfer system which was freed by
removing the pipes on the vessel outlets and taking out the
carbon lumps which bridged the bore of the pipe.
- 145 -
-------
The analytical instruments were calibrated and the boiler SO2
analyser showed considerable drifting about the calibration
point and a new amplifier was installed. Corrections were
made to previous data affected by this error assuming a
linear build up of the error from the last calibration point.
1.3.73 (Day 24)
The stone feed rate of 3O kgs/h (55 Ibs/h) over the first few
hours had not built up the bed height significantly and the
rate was increased to 36 kgs/h (79 Ibs/h). The first period
of this day was quite smooth without any significant mechanic-
al problems.
At 12.15 the make up rate was reduced to 15.9 kgs/h .(35 Ibs/h)
stone feed and conditions lined out with fairly smooth
operation of the plant. At 22.OO there were further problems
with the Wostoff "boiler 803 analyser giving a higher value
for the calibrant gas than normal. Back up analysis by
Draeger on the boiler line gave higher values than the S02
analyser but the sample temperature was higher than ambient
which would introduce some error in measurement.
2.3.73 (Day 25)
At O5.3O a complete set of samples were taken of the bed
material and at the dust collection points. Further invest-
igations were made into the effect of moisture in the boiler
sample line by frequent replacement of filters and higher SO2
values were subsequently recorded. At 14.OO a further set
of samples was collected. The regenerator bottom tapping
blocked periodically but it was cleared using the nitrogen
lance.
3.3.73 (Day 26)
The gasifier gas space pressure was gradually rising towards
the maximum recommended level and a set of samples was taken
at O4.OO with a stoichometric stone feedrate before raising
the stone feed rate to obtain two more data points before
shut down. There was a pilot flame failure at 14.3O but it
restarted after the flame eye was cleaned and replaced.
Further calibration checks were made on the boiler S02
analyser which again had drifted away from its previous level.
An appropriate correction factor was used in the analyser over
the period since the last calibration was made assuming that
a linear drift had occurred.
- 146 -
-------
At 18.00 the last set of samples was taken prior to a
controlled shut down at 19.OO completing Run 5. After the
shut down all air entry points to the unit were closed and
a small purge of nitrogen was introduced into the bed so
that the carbon present in the unit would not be burnt away
before an inspection could be made.
- 147 -
-------
APPENDIX B
CAFB RUN 5
INSPECTION
Gasifier and Regenerator Unit
Gasifier Concrete
The walls of the gasifier were generally blackened with carbon
and in the upper regions around the junction between flue
lid and the walls the carbon was up to 6.3 mm (V) thick.
There were patches immediately above the cyclone inlet ducts
where the carbon had burnt away suggesting that an air leak
has occurred after the shut down. In the lower areas, the
wall was glazed with a hard thin tenacious carbon deposit.
The cracks in the concrete hot faces which have been present
from the first firing of the unit showed their customary fine
black deposit of carbon about 25 mm (1") wide in the upper
areas of the wall. The lower areas were clean because of
the splashing action of the bed material. There was no sign
of any deterioration in the concrete from this test run.
There were areas at the junctions between the distributor and
the walls where a deposit of fine material had agglomerated
together to form a small covering between the distributor and
the wall, most likely caused by an area of poor fluidisation
due to a blocked or partially blocked distributor nozzle.
Gasifier Penetrations
The thermocouples, fuel injectors and pressure tappings were
in good order throughout although the left hand fuel injector
had been replaced during the run.
The thermocouple in the lid had a considerable growth of
carbon around its protruding end whilst those in the bed area
were generally clean, apart from the one at the lowest point
in the bed close to the fines return pipe. There was some
agglomeration of lime and carbon bridging between this
thermocouple, the distributor and the gasifier wall. This
condition probably arose from poor local fluidisation due
to an obstructed nozzle in the distributor together with the
introduction of the fines from the return system into this
- 148 -
-------
poorly fluidised zone. This thermocouple did show a
consistently low reading during the latter part of the run
which was probably caused by this local static material.
The fuel injectors were layered with carbon on their
protruding sections and the injector at the right hand side
had a hollow cap of carbon and lime enclosing its end.
The two air injection tubes which pass through the lid to
direct air into the cyclone inlets were both heavily scaled
and burnt away at their protruding tips.
The stainless steel tubes for the stone feed and fines return
were both in good order.
Cyclones
The cyclone bodies and their inlet sections which had both
been lined with type 310 stainless steel to improve their
surface finish and hence performance were heavily obstructed
with a mixture of carbon and lime.
The inlet ducts are illustrated in figure B-l and figure B-2
which show the black deposits around the inlets which
gradually become lighter further into the cyclone.
The white area on the gaisifer wall immediately above the
cyclone inlets can only be explained by some areas of carbon
burning out after the unit was shut down possibly due to some
local movements which may have broken any seals existing
between the underside of the lid and the gasifier wall.
Figure B-l also shows the white irregular deposits on the
cyclone outlet tube which can be seen hanging down inside
the cyclone body.
Figure B-3 shows a view into the right hand cyclone after
removal of the outlet tube shown in figure B-4. The cyclone
upper body was obstructed around its total circumference
leaving the hole in the centre formed by the outlet tube.
The material was laid down in a very irregular manner
consisting of layers and folds of fine hard material with a
tortuous gas path amongst this deposit. The deposit becomes
less pronounced towards the bottom of the cyclone compared
to the upper section, but still filled a considerable volume
of the lower section. The stainless steel liner was badly
scaled and distorted, in some areas it was completely burnt
away due to the high surface temperatures when carbon was
- 149 -
-------
burnt off at the various burn out operations during the run.
In the upper sections of the cyclone the liner was soft and
easily broken into flakes but nearer the bottom of the cone
the lining was generally stronger and some quite large pieces
of steel were removed intact. The steel lining tube which
sealed off the cyclone drain passage to the gasifier to
regenerator transfer line was heavily scaled with a small
area burnt away on the top retaining collar.
The deposit at the intersection of the rectangular inlet with
the cylindrical cyclone body was layered with white fine
material separated by thinner blacker layers, suggesting that
the thicker white layers are laid down during some of the
combusting periods. This is confirmed by the batch unit tests
which showed that combusting conditions give rise to the
most severe material deposition.
The silicon carbide outlet tube of the right hand cyclone
shown in figure B-4 was removed with very little material
adhering to the outer surface. Inside the tube there was an
overall thin layer of carbon and lime about 1.6 mm (1/16")
thick deposited around the bore and in some areas near the
bottom of the tube there were thicker irregular deposits up
to 15.9 mm (%") thick. These thicker layers could be removed
fairly easily but the thinner layers were very firmly bonded
to the tube.
The left hand cyclone was also severely blocked in the inlet
section and in the body of the cyclone although it was not
so severe as the right hand cyclone (figure B-5). The
cyclone outlet tube was coated on its outside with a thick
black flakey deposit (figure B-6) but the deposits did not
completely bridge across the gas passage between the outlet
tube and the cyclone wall.
The bore of the tube was coated with a layer of carbon and
lime about 1.6 mm (1/16") thick deposited fairly evenly over
the surface of the tube.
The stainless steel cyclone liner was severely scaled and
locally distorted or burnt away in many locations near the
top of the cyclone. Towards the lower end the lining was
almost intact although still heavily scaled.
The stainless steel tube sealing off the drain to the
regenerator to gasifier transfer line was heavily scaled and
around the upper outside surface there were crystalline
deposits of carbon which could have come up the transfer line
- 150 -
-------
from the gasifier bed. The upper retaining collar around
the tube had burnt completely away.
Gasifier Distributor
The distributor was generally in good condition apart from
some obstruction in the holes in the nozzles. The obstruction
arose from two sources - one was from lime particles which
entered from the gasifier bed and the other deposits have
come from fine rust scale carried through from the flue gas
recycle line which was carrying a saturated gas from the
water scrubber.
The distributor nozzle design has three staggered holes in
series with each other, the first smaller one to provide the
pressure drop needed in a fluid bed distributor and the third
larger one provides a low exit velocity to minimise damage
to the stone in the bed. The middle hole forms a plenum
between the inlet and outlet holes.
Generally, the outer holes were obstructed more with lime
particles and the inner holes with deposits of rusty coloured
material. There were considerable problems encountered in
removing the distributor because it had become wedged with
limestone and heavy fuel oil when one of the fuel injectors
failed during the run. Some of the mechanical force used to
remove the distributor may have dislodged some of the
material found in the nozzles but examination did show that
42 of the 192 outlets were obstructed completely, 18 of the
inlet holes were completely blocked, 1O9 partly obstructed
and the remaining 65 holes were clear.
The stainless steel material used for the nozzles was in
excellent condition and showed no sign of deterioration.
Gasifier Lid
The lid was heavily coated with carbon on its lower face and
the protruding thermocouple had a considerable deposit of
carbon around it. The refractory concrete was in good
condition but the vermiculite and calcium silicate insulating
slab was cracked in a number of places.
Gasifier Bed Material
The gasifier bed was slumped without sulphation at shut down
and figure B-7 shows the typical bed material after half the
material had been removed. There are two interesting
- 151 -
-------
features in this picture, one of them being the random area
of completely white material which proved to be an area of
fine particles free of carbon obviously formed after the bed
was slumped which must then have had some oxygen in-leakage
to burn off the carbon. This area of carbon free material
existed in about the middle third of the bed depth. Another
interesting and typical feature is the blackened area at the
right hand side which corresponds to No.l fuel injector
location. After further bed removal this fuel injector was
found to be encased with a hollow sphere about 1O cm (4")
diameter of carbon and lime particles which would have
restricted the throw of the injector.
The material was generally free from any large agglomerates
apart from a few lumps of carbon and fine lime particles up
to 3.8 cm (IV) across. There were some areas where there
had been static zones in the fluid bed around the periphery
of the distributor particularly near the fines return pipe
from the elutriator shown in the right hand side of fig. B-8.
Regenerator
The regenerator material was free from agglomerates and the
bore of the regenerator was generally clean apart from a few
small deposits at the top outlet section and around the joint
between the distributor and the wall. The refractory did
not show any deterioration.
The distributor was in good condition with the nozzles clear
and undamaged. The refractory lip around the distributor
had cracked away during the run and the repair that was made
had withstood the remainder of the run without any
deterioration.
The transfer passages to and from the regenerator were free
of any agglomerates and the refractory concrete around the
transfer sections was in good condition.
Ductwork and Burner
Gasifier Outlet and Burner
The bifurcated duct had a uniform deposit of carbon on its
inner surface about 1.6 mm (1/16") thick and at the junction
between the two ducts there were thicker deposits where the
two gas streams converged. The thermocouple in this area,
was heavily coated with a carbon and lime layer about 12 mm
(V) thick.
- 152 -
-------
The premix section upstream of the burner had a 1.6 mm (1/16")
carbon layer on the stainless steel sections and the 3.2 mm
(^") diameter stainless steel thermocouple in the burner
throat was burnt away.
The main burner was in good shape with a layer of carbon
about 1.6 mm (1/16") thick deposited on the internal gas
ductwork. The outlet ring of the burner had a local build
up mainly of lime on its outer face shown in fig. B-9 which
was deposited from the turbulence in the gas streams arising
from the stainless steel baffle plates located to shield
the pilot flame from the main combustion air.
The pilot burner which had been very successfully modified
to provide a forced gas and air premix system prior to the
flame retention nozzle was in good condition apart from some
local lime deposits around the nozzle end which protruded into
the burner guarl in the boiler.
The stainless steel deflector plates in the boiler burner
quarl were heavily deposited with lime.
Regenerator outlet
The outlet pipe from the regenerator top gas space was coated
with long thin light purple deposits of material laid along
in the direction of flow and projecting out from the wall of
the duct (figure B-1O). In one area there was one projection
which extended out almost 25 mm (1") from the wall but generally
they were 12 mm (V) or less and only about 3 mm (V) thick at
the furthest tip. They were held fairly firmly to the wall and
appeared to have passed through a molten phase having a fairly
smooth outer face. Further downstream the pipe was coated
with a much more uniform deposit about 3 mm (V) thick which
was composed of fine particles rather than the liquid type
of deposition in the hotter upstream section of the pipe
(Figure B-ll).
Downstream of the dust extraction cyclone the pipe was clean
apart from a very thin white fine deposit.
Boiler and Stack (
Boiler
The back end of the boiler had been cleaned periodically
during the test run and figure B-12 shows the condition after
shut down. There was some coarser material laying in the
- 153 -
-------
bottom of the boiler fire tube with some finer material
deposited around the lower sides of the fire tube mainly on
the left hand side when viewed from the rear, indicating
that there was some swirl in the flame at the burner.
The entries to the first pass of fire 'tubes were deposited
with rings of fine material although none of the tubes was
totally blocked. Some of the deposits were smooth and
rounded whilst others were spikey, shown clearly in figure
B-13.
The return tube passes were generally clear apart from a few
tubes which had some deposits at their ends. Some material
had been deposited out of the gas stream and collected in the
boiler space at the end of this second tube pass.
The refractory on the boiler rear door showed some signs of
pitting but there has been a gradual deterioration not just
associated with this particular run.
Boiler Probe
The boiler probe acquired some local light brown lumpy
deposits which tended to be more concentrated around the
"root" of tube figure B-14, in front of the entrance to the
first tube pass. There was no indication of any deterioration
of the tube which was cooled during the run to approximately
6OO°C.
Stack and Cyclone
There was a quantity of lime at the base of chimney which
was otherwise clean and the external cyclone and knock out
pot was also clear of any obstruction. Both these vessels
were continually rapped during the run and this prevented any
significant build up of material.
Flue Gas Scrubber and Recycle Line
Scrubber
Taere were considerable operational problems with the
scrubber initially due to the wet fine slurry which was
discharged and the deposits which built up at the scrubber
entry. The problems were eased by running the scrubber with
some recycle so reducing the dust burden concentration and
increasing the velocity of the gas and hence effeciency of
operation.
- 154 -
-------
Examination afterwards showed that the knock out vessel had
some hard fine deposits on its wall opposite the gas entry
when the material would first impinge on the wall. The
scrubber and its entry pipe was clear.
Recycle Line
The scrubber has cleaned up the solids content of the gas
very well but introduced some problems due to the cold
saturated gas leaving the scrubber which contained enough
very fine particles to seize up the cycle line control
butterfly valve and the control valve to the burner air
valve which was in a static leg and probably contained a
considerable quantity of condensation.
- 155 -
-------
Figure B-l R.H. Cyclone Inlet
Figure B-2 L.H. Cyclone Inlet
- 156 -
-------
Figure B-3 R.H. Cyclone, Outlet Tube Removed
Figure B-4 R.H. Cyclone Outlet Tube
- 157 -
-------
Figure B-5-L.H. Cyclone, Outlet Tube Removed
Figure B-6 L.H. Cyclone Outlet Tube
- 158 -
-------
Figure B-7 Gasifier Bed Half Removed
Figure B-8 Gasifier Bed Empty
- 159 -
-------
Figure B-9 Main Burner Outlet Ring
Figure B-10 Regenerator Outlet Pipe, Upstream End
- 160 -
-------
Figure B-ll Regenerator Outlet Pipe, Downstream End
Figure B-12 Boiler Back End After Shut Down
- 161 -
-------
Figure B-13 Fire Tube First Pass Inlets
Figure B-14 Boiler Probe
- 162 -
-------
Fig. C.I Gasifier cyclone inlets
Fig. C.2 L.H. cyclone inlet
- 261 -
-------
RUN 5:
DAY.HOUR
2.
2,
2.
2,
2.
2.
2.
2.
2.
2.
2.
2.
2.
2.
2,
2-
2.
2.
2.
2.
2.
2.
2.
3-
.0130
.0230
.0330
.0430
.0530
.0630
.0730
.0830
.0930
. 1030
. 1 130
. 1230
• 1330
. 1430
• 1530
. 1630
• 1730
• 1830
• 1930
• 2030
• 2130
.2230
.2330
.0030
3.0130
3.0230
3.0330
3.0430
3.0530
3-0630
.0730
.0830
.0930
. 1030
.1130
1230
. 1330
1430
1530
1630
3.
3.
3.
3.
3.
3.
3.
3.
3-
3.
APPENDIX B
: TABLE
I .
TEMPERATURES AND FEED RATES PAGI
TEMPERATURE* DEG.
GASIFIER
933.
923.
939.
948.
940.
940.
933.
940.
952.
882.
880.
885.
888.
882.
895.
892.
880.
880.
890.
882.
873.
880.
890.
882.
884.
889.
890.
888.
891 .
899.
897.
891 .
891 .
892.
882.
882.
881 .
886.
c.
REGEN. RECYCLE
1067.
1078.
1069.
1060.
1038.
1053.
1050.
MISSED DATA
1060.
1055.
1030.
1060.
1050.
1050.
1050.
1050.
1050.
1 0 48 •
1048.
1070.
1023-
1040.
1048.
1052.
MISSED DATA
1061 .
1062.
1065.
1063.
1057.
1058.
1060.
1055.
1041 .
1055.
1055.
1060.
1070.
1061 •
1065.
72.
72.
75.
76.
76.
76.
77.
READING
75-
75.
75.
72.
75.
75.
80.
80.
80.
75.
75.
80.
85-
95.
80.
78-
READING
78.
80.
79.
80.
75.
75.
75.
70.
70.
70.
70.
70.
70.
70.
60.
FEED 1
OIL
182.6
18?. 1
175- 1
175. 1
174.7
174.7
174.3
1 77.2
187. 1
187. 1
183.8
182. 1
180. 1
183.0
183.8
180.9
179.3
1 79-3
180. 1
180. 1
1 79.7
180.5
171.4
182. 1
173-9
176.8
180.5
181.7
180.5
181.3
177.2
179.3
180. 1
177.6
181.7
1 79. 7
173.5
173.5
1 OF 9
RATE
KG/HR
STONE
34. 5
28.6
10.0
0.
2. 5
2.5
1 .8
3.6
5.0
5.9
5.4
6. 4
7.3
7. 7
8-2
7.7
9. 1
9. 1
8.2
8.2
8.2
9. 1
10.0
9. 1
9.5
8.6
8.2
7.3
8.6
8.6
9.1
6.8
5.9
5.9
6. 4
7.5
7.0
6. 4
- 163 -
-------
APPENDIX B: TABLE I.
RUN 5: TEMPERATURES AND FEED RATES PAGE
2 OF 9
DAY. HOUR
TEMPERATURE*
DEG. C.
GASIFIER REGEN. RECYCLE
3. 1730
3. 1830
3. 1930
3.2030
3.2130
3.2230
3.2330
4.0030
4.0130
4.0230
4.0330
4.0430
4.0530
4.0630
4.0730
4.0830
4.0930
4. 1030
4* 1 130
4. 1230
4. 1330
4. 1430
4.1530
4.1630
4- 1730
4. 1830
4. 1930
4.2030
4.2130
4.2230
4*2330
5.0030
5.0130
5*0230
5.0330
5.0430
5.0530
5*0630
5*0730
896.
890.
900.
895.
892.
902.
892.
901.
876.
831.
888.
910.
850.
850.
853.
859.
870.
870.
868.
875.
861.
862.
852.
858*
860.
862.
860.
862.
865.
873.
880*
867.
848.
858*
858.
858*
859.
1061 .
1062.
1065.
1068*
1070.
1065.
1067.
1062*
STONE
1062.
1055*
1060.
1065*
1067.
1068.
1066.
1067.
1050.
1050.
1070.
1020.
MISSED
1050*
1055.
1049.
1050.
1050.
1058.
1052.
1051.
1053*
1052.
1055.
MISSED
1059.
1050.
1058*
1052.
1058.
1058.
70.
70.
75-
70.
80.
85.
83.
83.
CHANGE
82*
82.
82.
83.
55.
65.
80.
80.
78.
78.
78.
78.
DATA READING
80.
80.
80.
80.
80.
80.
80.
86.
85.
60*
75.
DATA READING
80.
82.
80.
85.
82.
80.
FEED RATE KG/HR
OIL
165.2
190.0
169.3
198.3
180. 1
179.7
179.3
171.4
182.6
182.1
173-9
176.8
180.5
181 .7
180.5
181.3
177.2
179.3
180*1
177.6
177.2
178.8
176.4
178.4
178.0
179.3
180.1
177.6
177.6
173.5
186.7
168*9
174*7
187.9
180.9
180.9
180* 1
STONE
7.7
9-5
8.2
8.6
9.5
5.9
0.
0.
0.
0.
0.
0.
45.8
61 .7
49.9
25.9
8.6
0.
0.
22.2
28.6
29.5
28.1
27.7
35.4
38*6
35.4
26.8
27.2
28.6
33.1
28*6
29.0
30.4
29.0
28.6
22.7
- 164 -
-------
RUN 5:
APPENDIX Bt TABLE I.
TEMPERATURES AND FEED RATES PAGE
3 OF 9
AY. HOUR
5.0830
5.0930
5. 1030
5.1130
5. 1230
5. 1330
5*1430
5. 1530
5. 1630
TEMPERATURE* DEG. C. FEED RATE KG/HR
GASIFIER
858*
845.
845.
851 •
848.
870.
872.
888.
REGEN. RECYCLE OIL
1052.
1050.
1050.
1050.
1049.
MISSED
1055.
1055.
1054*
80.
80.
80.
80.
80.
DATA READING
80.
80.
80*
80.9
80*9
80. 1
80. 1
79.7
75.1
74.3
74.3
STONE
29.5
38.1
30.6
29.0
19. 1
13.6
13.2
15.9
5.0830
5.0930
5. 1030
5.1130
5. 1230
5. 1330
5.1430
5. 1530
5. 1630
SHUT
6.0230
6.0330
6.0430
6.0530
6.0630
6.0730
6.0830
SHUT
8.2230
8.2330
9.0030
9.0130
9.0230
9.0330
9.0430
9.0530
SHUT
11*1 430
11.1530
11*1630
1 1 .1730
858*
845.
845.
851 •
848.
870.
872.
888.
DOWN AT
865.
862.
852.
868.
852.
850.
850.
DOWN AT
895.
890.
872.
870.
875.
872.
880.
882.
DOWN AT
871.
860.
860.
866*
5-1630 FOR 10 HOURS
1049.
1050.
1054.
1050.
1060.
1055.
1065.
85.
83-
80.
85.
83.
83.
82.
6.0830 FOR 62 HOURS
1005*
1035*
1062*
1042.
1042*
1048*
1060.
1055.
70.
70.
70.
70.
70.
72.
72.
72.
9.0530 FOR 57 HOURS
1060.
1060.
1062*
1064.
80.
80*
80.
80*
171.8
171.8
173.5
172.2
172.6
172.2
166*0
172.2
171.8
173.1
177.6
177.2
177.6
176.8
177.6
177.2
185.9
177.6
177.6
14
22
21
20
18
17
18
5
2
3
9
1
,7
.6
24.5
24.9
32.2
33.6
29.9
26.8
19.5
15.4
39.5
37.6
15-9
15.9
- 165 -
-------
APPENDIX B: TABLE I.
RUN 5: TEMPERATURES AND FEED RATES PAGE
4 OF 9
DAY. HOUR
TEMPERATURE*
GASIFIER REGEN
1 '1830
1 .1930
1 .2030
1 -2130
1 .2230
1 .2330
12.0030
12.0130
12.0230
12.0330
12.0430
12.0530
12.0630
12.0730
12.0830
12.0930
12* 1030
1 2 • 1 1 30
12.1230
12* 1330
12* 1430
12.1530
12.1630
12. 1730
12.1830
12.1930
12.2030
12.2130
12.2230
12*2330
13*0030
13*0130
13*0230
13*0330
13.0430
13.0530
13.0630
879.
882.
892.
892.
880.
867.
869.
875.
881.
880.
881*
879.
875.
872.
868*
865.
875.
868.
868.
870.
868*
865.
876*
878.
874.
871.
878*
875.
865.
862.
870.
875.
880.
880.
870.
1069.
1068*
1075.
1067.
1068*
1068.
1065.
MISSED
1065.
1065.
1050.
1050.
1050.
1050.
1050.
1042.
1042.
MISSED
1030.
1040.
1035.
1042.
1071.
1049.
1071 .
1028.
1030.
1012.
1075.
1020*
1020.
1025.
1060.
1020.
1020.
1035.
1020.
DEG. C.
. RECYCLE
74.
80.
80.
88.
85.
80.
83*
DATA READING
82.
80.
80.
80.
80.
75.
75.
75.
80.
DATA READING
80.
80.
80.
75.
83-
82.
85.
85*
85.
81.
80.
75.
75.
75.
75.
80.
80.
75.
75.
FEED RATE KG/HR
OIL
177.2
177.2
177.6
176-8
179.7
179.7
183.8
184*6
183*8
190.0
183.8
183*8
177.6
173.5
174.7
178.0
178.4
178.8
178.8
178.4
179.3
178.4
177.6
178.0
178.0
178.0
182*1
179.7
177.2
175.9
176.8
177.2
176.8
176*4
174.7
STONE
17.2
1 7.2
17.7
20.0
19. 1
20.9
24.0
17.7
12. 7
10.9
1 4* 1
1 5* 4
• *J » ^
10.9
1 5*4
21 .8
20.4
19. 1
18.6
18*8
21 .3
20.4
1 5*4
17.7
19. 1
17.2
18.8
17.9
15*9
19. 1
18. 1
15.4
15*4
15*6
12.7
15.0
- 166 -
-------
RUN 5:
APPENDIX B: TABLE I
TEMPERATURES AND FEED RATES
PAGE 5 OF 9
DAY.HOUR TEMPERATURE* DEC. C. FEED RATE KG/HR
GASIFIER REGEN. RECYCLE OIL STONE
SHUT DOWN AT 13-0630 FOR 73 HOURS
16.0730
16.0830
16.0930
16. 1030
16.1130
16*1230
16. 1330
16.1430
16*1530
$16.1630
16.1730
16.1830
16.1930
16*2030
16.2130
16.2230
16*2330
17.0030
1 7 . 0 1 30
17.0230
17.0330
17.0430
17.0530
17.0630
17.0730
17.0830
17.0930
17. 1030
17.1130
17.1230
17.1330
17.1430
17.1530
17. 1630
1 7.1730
17.1830
868.
875.
878.
868.
881.
866.
869.
870.
861*
865*
872.
865.
859.
855.
848.
862.
861.
870.
872.
872.
872.
876.
870.
869.
868.
861.
860.
861 .
862.
862*
865.
858*
860.
858.
990.
1070.
1068.
1070.
1029.
1050.
1051 •
MISSED
1060.
1060.
1060.
1061 .
1060.
1055.
975.
1012.
1050.
1061 •
1052.
1039.
1031 •
1038*
1039.
1020.
1059.
MISSED
1053.
1052.
1051 •
1050.
1048*
1058-
1041.
1041 .
1049*
1050.
80.
81.
81 .
80.
80.
79.
72.
DATA READING
72.
71.
71.
71.
70.
70.
70.
72.
72.
72-
71 .
70.
70.
70.
62.
70.
70.
DATA READING
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
174.7
174.7
175.5
175.1
174.7
175.5
173.5
1 71 .8
172.2
172.2
172.2
172.2
171.4
181.7
181.7
178.8
179.3
180.1
179.3
180.1
188.8
171 .0
180.1
1 79.3
180*1
179.3
180*1
180-9
180*1
185.9
178.8
179.7
179.3
179.3
17.7
25.4
24.9
22.2
20.4
27.7
28*6
27.2
29.5
31.8
34.9
34.0
33.1
33-1
33.6
15*4
16.3
15.0
15.4
18. 1
13*6
20.4
18. 1
18.6
6.9
20.9
17. 1
16*8
20.0
22.7
31.3
30.8
22.2
19.5
- 167
-------
APPENDIX B: TABLE
RUN 5:
DAY. HOUR
17.1930
17.2030
SHUT
2(9.2030
20.2130
20.2230
20.2330
21 .0030
21 .0130
21 .0230
21 .0330
21 .0430
21 .0530
21 .0630
21.0730
21 .0830
21 .0930
21 • 1030
21 . 1 130
21 . 1230
21*1330
21*1430
21*1530
21*1630
21 .1730
21 .1830
21 • 1930
21 .2030
21*2130
21 .2230
21*2330
22*0030
22*0130
22*0230
22*0330
22*0430
I .
TEMPERATURES AND FEED RATES PAG
TEMPERATURE*
GASIFIER
869.
862.
DOWN AT 1
918.
900.
888.
890.
915.
915.
915.
910.
905.
902.
914.
900.
898-
901.
900.
899.
900.
903*
901.
889.
895.
898.
875.
893.
892.
860.
856.
870.
871.
871.
878.
872.
874.
REGEN
1051 •
1050.
STONE
7.2030
1012*
1012.
1055.
1052.
1055*
1053.
1060*
1058.
1060.
1060*
1060*
1060*
1060.
1067.
1064*
1061.
1062*
1065.
1068.
1064.
1063*
1066*
1066*
1069*
1069*
1069.
1068.
1071.
1068*
1070.
1068.
1069.
1070.
DEG. C.
. RECYCLE
65.
68.
CHANGE
FOR 72 HOURS
65.
68.
70.
70.
65.
65.
60.
65*
65*
65.
65.
65.
62*
65*
65.
65.
66.
63*
62*
64.
63*
62*
66.
60*
70.
70.
70.
70*
70.
70.
70.
70.
70.
FEED
OIL
179.3
179.3
193*3
197.8
205-3
208.6
208.6
196.2
211.1
215*6
212.7
212.7
21 1 .9
211.5
215.6
207*3
211.5
211.1
211.5
211 .5
211*1
213*1
213*9
213*1
210.2
212*3
196*6
184*6
188*3
187.9
185*4
187.9
184.2
185*9
190.0
6 OF 9
RATE
KG/HR
STONE
18. 1
16*3
39.9
23.1
26.8
27.2
25.9
24.0
25.4
19.1
21 .8
21.8
19.1
20.4
20*4
17.2
19.5
20.4
20.9
23.1
21.8
23-6
23*1
23*6
23*1
24.9
15*9
10*4
13*6
18*1
21*8
20*9
14*1
16*8
13*6
- 168 -
-------
RUN 5:
APPENDIX B: TABLE I•
TEMPERATURES AND FEED RATES PAGE
7 OF 9
DAY .HOUR
22.0530
22.0630
22.0730
22.0830
22.0930
22.1030
22. 11 30
22.1230
22. 1330
22.1430
22.1530
22. 1630
22.1730
22.1830
TEMPERATURE* DEC. C.
GASIFIER
875.
875.
888.
875.
872.
872.
871.
875.
873.
875.
872.
871.
877.
873.
REGEN.
1069.
1070.
1070.
1070.
1071.
1069*
1064.
1065*
1069.
1070.
1069.
1069.
1071.
1068.
RECYCLE
70.
70.
70.
70.
72.
72.
72.
72.
72.
72-
71.
72.
71.
70.
FEED RATE KG/HR
OIL
191.2
183.0
181.7
190.8
186.3
185.4
185.0
185.4
189.6
184*6
184.6
184.6
185.4
184*2
STONE
13-6
14.5
14.5
16.3
16.3
14*5
13.2
1 4.5
15.4
13.2
13*6
16*3
13.6
15.9
SHUT DOWN AT 22-1830 FOR 23 HOURS
23. 1730
23. 1830
23. 1930
23*2030
23.2130
23.2230
23.2330
24.0030
24.0130
24.0230
24.0330
24.0430
24.0530
24.0630
24.0730
24*0830
24*0930
24*1030
24.1 130
24.1230
24*1330
24* 1430
891.
869.
868.
869*
860*
858*
866*
862*
869.
862.
865.
862.
860.
861*
865*
878.
873*
873*
885*
879*
875*
870*
1053-
1055*
1052*
1061 •
1061*
1060*
1060*
1060*
1060*
1060*
1060*
1055.
1054*
1059*
1061*
1061*
1061*
1061*
1060*
1061*
1061*
1060*
75*
75*
75.
74*
75*
75*
75.
75.
75.
75.
75.
75.
74*
75*
74*
72*
72*
70.
72*
71.
72.
70.
177.6
182*6
178.4
178*0
179*7
178*8
178-4
179.7
181.7
183*0
184*6
184*6
185.4
185*0
186*3
185.4
185.9
184*6
181*3
184*6
185*0
184*6
32*2
33* 1
33* 1
30*4
30*4
31*8
31.8
31-8
31*8
32*2
29*9
29*0
30.4
28-6
29*0
35*4
35.4
31.3
32.2
27.2
9*5
13*6
- 169 -
-------
APPENDIX B: TABLE I.
RUN 5: TEMPERATURES AND FEED RATES PAGE
8 OF 9
DAY. HOUR
TEMPERATURE* DEG. C.
GASIFIER REGEN.
24* 1530
24* 1630
24.1730
24.1830
24. 1930
24.2030
24.2130
24.2230
24.2330
25*0030
25.0130
25.0230
25.0330
25.0430
25.0530
25.0630
25.0730
25.0830
25.0930
25. 1030
25. I 130
25. 1230
25.1330
25.1430
25.1530
25* 1630
25. 1730
25.1830
25. 1930
25*2030
25.2130
25.2230
25*2330
26*0030
26*0130
26*0230
26*0330
26*0430
26*0530
26*0630
870.
869*
869.
871.
865.
870.
876*
875.
883*
870.
878.
874.
880.
880.
880*
880.
880.
878.
880.
883.
890.
870.
878.
878.
873.
878.
871.
881.
879.
883*
882*
881*
876.
871.
872.
870.
878.
888.
885.
886.
1060*
1060.
1059.
1060.
1060.
1061*
1060.
1060.
1060.
1060.
1062*
1060.
1060.
1060*
1060.
1060.
1060.
1060.
1060.
1061.
1060.
1060.
1059*
1060*
1060.
1060*
1060*
1061 .
1061 *
1060*
1060.
1060.
1058.
1060.
1060.
1060.
1060.
1060.
1060.
1060.
RECYCLE
70.
75.
72.
75.
75.
75.
71.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
75.
75.
70.
73.
75-
75.
75.
75.
75.
75.
74.
74.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
FEED RATE KG/HR
OIL
185.4
184.6
184.2
185*0
183*8
183.8
183*4
183*4
183*4
183*8
183*4
183*4
183*4
182* I
182.6
182.6
181.3
181*3
182* 1
183.0
181*7
182* 1
181 .7
183*0
182. 1
180.9
186.3
184.6
185.4
185.0
185.9
185.4
184*6
184.6
185*0
185*4
184*6
185.0
185*0
185.0
STONE
1 7*2
* * ™ C-
18* 1
21.3
20*9
23.6
*•« *•/ ^ \j
21 .8
21 • T
* v *J
23.6
20 . 4
^.T> • *f
23.6
24. 5
22. 7
23*6
1R . 1
1 O • 1
20*4
22.2
19.1
1 7 • |
Op. p
<— C. • C
P0 • 4
C- c / • *<
22.2
17.7
1 * • r
21.3
<— 1 • \J
20. 4
19* 1
• r • I
16.8
19. 5
1 3*6
15*0
14*5
A ^ * ••/
16*3
1 4* 1
16*3
16.3
16*3
14. 5
15.9
14.5
15.4
14*5
12.2
- 170 -
-------
APPENDIX B: TABLE I.
RUN 5: TEMPERATURES AND FEED RATES PAGE 9 OF 9
DAY. HOUR
26*0730
26.0830
26.0930
26* 1030
26. 1 130
26. 1230
26.1330
26*1430
26*1530
26* 1630
26* 1730
26. 1830
TEMPERATURE* DEC* C.
GASIFIER
866-
870.
872*
862.
860*
864*
868.
865*
868*
870*
877.
872.
REGEN.
1060.
1060*
1060.
1060.
1060.
1060*
1060*
1062*
1060*
1060*
1062*
1059*
RECYCLE
70*
70.
70.
70.
70*
70.
74*
74*
73*
74*
74*
72*
FEED RATE KG/HR
OIL
185*0
185*0
184*6
185*9
185*0
185*4
184.6
185*0
184.6
185*4
184.2
184.2
STONE
19.5
20.0
17.2
19.5
20. 0
20.4
19*1
20-4
23-6
19*5
19.1
19.5
- 171 -
-------
APPENDIX B: TABLE II.
RUN 5: GAS FLOW RATES
PAGE 1 OF 9
DAY. HOUR
GAS
GASIFIER
AIR FLUE GAS
2. PI 130
2.0230
2.0330
2*0430
2.0530
2.0630
2.0730
2.0830
2.0930
2. 1030
2. 1 130
2. 1230
2. 1330
2. 1430
2.1530
2. 1630
2. 1730
2. 1830
2. 1930
2.2030
2*2130
2.2230
2.2330
3*0030
3.0130
3.0230
3.0330
3*0430
3.0530
3.0630
3.0730
3*0830
3*0930
3*1030
3*1130
3*1230
3*1330
3*1430
3.1530
3*1630
445*
445*
402.
419.
419.
419.
431 .
456.
421.
404.
396.
404.
387.
397.
397.
388.
362.
362.
379.
380.
362.
380.
380.
380.
380*
380*
379.
388*
388*
388*
397.
379.
397.
397.
379.
379.
379.
379.
149.
1 50.
20 .
19 .
19 *
18 *
18 *
MISSED
159.
210.
352.
229.
220*
220.
212.
212.
202*
179.
179.
164*
208.
193*
167.
162*
MISSED
156.
152.
152*
148*
140.
140*
140.
135*
160.
177.
171.
177.
189.
189*
177.
RATES M3/HR REGEN.
PILOT REGENERATOR VELOCITY
PROPANE AIR NITROGEN M/SEC
3.3
3.3
3.1
3. 1
3.2
3.2
3.2
DATA
3.2
3.2
3«2
3.3
3.3
3.3
3.3
3.3
3-3
3.3
3.3
3.3
3.3
3.3
3*3
3.3
DATA
3.3
3.3
3-3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3*3
3.3
3.3
3.1
30.2
31 .7
23.9
25.6
28.5
25.1
22.7
READING
25.2
28.0
30.3
31 .2
29.7
30.4
30.5
29.9
29.6
26.4
26.4
27.7
22.5
30. 1
32.6
30.7
READING
31 .7
32.2
33.4
33.4
33.5
33-1
32.9
32.2
30.8
30.8
30.3
33.3
30.7
30.6
30.4
3.3 .54
3.3
3-3
3.3
3.3
3»3
3-3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3* 3
3-3
3.3
3*3
3.3
3.3
3.3
3*3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3*3
3*3
3*3
3*3
3*3
• 63
• 25
• 32
• 42
• 29
* 18
• 30
• 42
* 50
• 58
* 50
• 53
• 53
• 51
• 49
• 35
• 35
w •/
• 44
• 1 5
• 51
.64
. 55
• 61
. 63
. 70
• 69
• 69
• 67
• 66
• 62
• 54
• 56
.53
.67
• 57
.55
.55
- 172 -
-------
APPENDIX B: TABLE II.
RUN 5: GAS FLOW RATES
PAGE 2 OF 9
DAY. HOUR
GASI
GAS
FIER
AIR FLUE GAS
3. 1730
3 • 1 8 30
3. 1930
3.2030
3.2130
3.2230
3.2330
4.0030
4.0130
4.0230
4.0330
4.0430
4.0530
4.0630
4.0730
4.0830
4.0930
4.1030
4.1 130
4.1230
4. 1330
4.1430
4. 1530
4.1630
4.1730
4.1830
4. 1930
4.2030
4.2130
4.2230
4.2330
5.0030
5.0130
5.0230
5.0330
5.0430
5.0530
5.0630
5.0730
379.
388.
388.
379.
384.
388.
381 .
382.
379.
380.
381 .
380.
356.
382.
382.
382.
380.
363.
363.
363*
385.
398.
395.
395.
394*
394.
395.
394.
395.
361.
378.
378.
378.
378.
395.
395.
395.
189.
180.
181 .
180.
181*
186.
185.
185.
STONE
58.
58.
54.
54.
89.
59.
53.
73.
62.
71.
90.
90.
MISSED
205.
199.
205.
194.
194.
194.
200.
210*
208*
218.
189.
MISSED
193.
195.
194.
197.
195.
193.
RATES
PILOT
PROPANE
3.3
2.9
3.2
3.3
3.3
3.3
3.3
3.3
CHANGE
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
DATA READI
3*2
3.2
3.2
3.3
3.2
3.2
3.2
3.5
3.5
3.5
3.5
DATA READI
3.5
3.4
3.5
3.5
3.5
3.5
M3/HR REGEN.
REGENERATOR VELOCITY
AIR NITROGEN M/SEC
25.0
31 .1
28.7
32.4
22.8
30*4
33.0
31.0
30.5
32* 1
32.6
33*8
33-8
33.8
33.5
33.3
32.5
31*1
31-1
30.7
NG
28.0
30.4
28.2
30.5
31*1
27.3
30.9
30.7
30.0
31-1
31 .6
NG
31.8
31.0
31*0
30.8
30*8
30.8
3.3 .29
3-3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.9
4.6
1 .9
.57
.47
• 64
• 20
.55
.67
.57
.55
• 61
.63
.70
.70
.70
.67
.67
.60
.54
.56
• 49
• 41
• 52
.41
.52
.54
• 38
.54
.53
.50
.55
• 60
.65
• 48
3.7 1.57
2.9 1.52
0.7 1.42
2-1 1.49
- 173 -
-------
APPENDIX B: TABLE I I.
RUN 5: GAS FLOW RATES
PAGE 3 OF 9
DAY. HOUR
GAS!
GAS
FIER
AIR FLUE GAS
5.0830
5.0930
5.1030
5.1130
5.1230
5.1330
5. 1430
5.1530
5.1630
395.
393.
393.
385.
367.
378.
387.
378.
193.
193.
193.
163*
173.
MISSED
172.
168*
162.
RATES M3/HR REGEN.
PILOT REGENERATOR VELOCITY
PROPANE AIR NITROGEN M/SEC
3.5
3.3
3*3
3.2
3*4
DATA
3.4
3.4
3.4
31*0
30.9
31.0
30.9
31.2
READING
30.2
29.8
27.5
1*6 .47
2.3
1 .6
2.1
1 .6
2*0
2.1
1.5
.49
.46
.49
• 48
.45
• 44
• 31
SHUT DOWN AT 5.1630 FOR 10 HOURS
6.0230
6.0330
6.0430
6.0530
6.0630
6.0730
6.0830
363.
363.
363.
362.
362.
380.
328.
218-
216.
203.
208.
185.
175.
174.
3.5
3.5
3.5
3.5
3.5
3.5
3.5
29.0
28.0
28.8
25-2
25.3
26.8
27.4
2.9
3.7
3.3
1 .7
1 .7
1 .6
1 .6
• 42
* 41
• 43
• 20
w b* mj
»?1
w C.-. I
• 26
v t» U
.30
SHUT DOWN AT 6.0830 FOR 62 HOURS
8*2230
8.2330
9.0030
9.0130
9*0230
9.0330
9.0430
9.0530
388.
380.
398-
380.
389.
397.
397.
397.
189.
189.
179.
173-
169.
169.
169.
159.
3.3
3.3
3.3
3.3
3*3
3.3
3.3
3.3
36. 1
35.9
38.1
38.4
39.8
39.9
43-5
44.4
2.8
3.3
3.3
2.6
3*6
4*4 £
4.8 £
4.8 'c
• 72
.77
>9 ]
• 86
• 97
>.03
>.23
>.26
SHUT DOWN AT 9.0530 FOR 57 HOURS
11.1430
11*1 530
1 1.1630
11 • 1730
387.
386.
386.
386.
205.
174.
173.
173.
3*5
3.5
3.3
3.3
34*4
35.9
36.7
36.7
6.7
7.2
6.2
6.2
1.88
1.98
1 .97
1.97
- 174 -
-------
APPENDIX B: TABLE I I.
RUN 5: GAS FLOW RATES
PAGE 4 OF 9
DAY.HOUR
1
1
1
1
1
1
12.
1830
1930
2030
2130
2230
2330
0030
12*0130
12*0230
12.0330
12.0430
12.0530
12.0630
12*0730
12.0830
12.0930
12.1030
1130
1230
1330
1430
1530
1630
1730
1830
1930
12.2030
12.2130
12.2230
12.2330
13.0030
13.0130
13.0230
13.0330
13*0430
13.0530
13.0630
12.
12.
12.
12.
12.
12.
12.
12.
12.
AIR
387.
404.
405.
404.
387.
387.
400.
396.
396.
396.
396.
379.
362.
362.
379.
380.
379.
379.
379.
378.
379.
379.
379.
379.
379.
379.
379.
362.
362.
361.
361 .
361.
362.
362.
361 .
GAS
ER
IE GAS
171.
160.
149.
157.
176.
172.
174.
MISSED
163.
162.
162.
162.
182.
190.
190.
160.
152.
MISSED
152.
152.
152.
140.
143.
143.
144*
144.
155.
173.
191.
210.
209.
209.
209.
212-
212.
209.
210.
RATES
PILOT
PROPANE
3.3
3.3
3.3
3.3
3.3
3.3
3.3
DATA READI
3.2
3.2
3.2
3*2
3.2
3.2
3.2
3*2
3.2
DATA READI
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3-3
1.7
3.3
3.3
3.3
M;
REGI
AIR
36.4
36. 1
36. 1
37.9
35.4
31 .6
34.5
NG
33.9
31.0
38.0
34.6
34.8
38.2
35. 1
35.4
36. 1
NG
35.9
35.7
35.7
36.4
35.8
35.7
35.1
35*8
35*8
35*8
37.6
36.9
35.7
35.7
36*1
36.9
36.4
36.8
37.4
NITROGEN
7.6
6.7
7.0
7.0
5.3
5*6
5.6
7.7
7.5
7.8
8*8
7.6
7.5
7.0
8.3
7.2
8.6
7.1
8.2
6.0
5.6
4.9
1 *5
4.7
4.7
4.7
5.0
7.5
4.5
6.8
6*8
7.2
7.2
7.1
7.2
REGEN.
VELOCITY
M/SEC
2.03
.97
.99
.07
• 87
• 71
.84
.91
.77
.08
.97
.93
>08
.91
.98
.96
• 99
.94
.98
.92
.92
.85
.69
.81
.81
• 79
.97
.97
• 78
.89
• 96
.95
.93
.97
.98
- 175 -
-------
APPENDIX B: TABLE II.
RUN 5: GAS FLOW RATES
PAGE 5 OF 9
DAY. HOUR
GASI
GAS
FIER
AIR FLUE GAS
SHUT
16.0730
16*0830
16.0930
16.1030
16.1130
16. 1230
16.1330
16. 1430
16*1530
16. 1630
16.1730
16. 1830
16. 1930
16*2030
16*2130
16*2230
16*2330
17.0030
17.0130
17.0230
17.0330
17.0430
17.0530
17.0630
17.0730
17.0830
17*0930
17. 1030
17.1130
17.1230
17.1330
17*1430
17.1530
17*1630
17.1730
17*1830
DOWN AT
391 .
387.
387.
387*
387.
387.
404.
404.
395.
404.
404.
395.
387.
395.
395*
396*
404*
405.
405.
405.
405*
405*
405.
405.
405*
405.
388.
405.
395.
421 .
421.
403*
421*
412.
13*0630
0*
19*
193.
193*
186*
192.
179.
MISSED
169.
148.
148*
1S8.
148.
148.
148.
149.
149*
149.
148*
148.
148.
148.
147.
148*
148.
MISSED
147.
147.
147.
127.
127.
137.
137.
137.
127.
127.
RATE
PILOT
PROPANE
S M
REG
AIR
FOR 73 HOURS
3.4
3.4
3*4
3.4
3.4
3.4
3*3
31 .9
31. 1
31 . 1
30.5
30*8
34.2
33.0
DATA READING
3-3
3*3
3.3
3*3
3*2
3.2
3.4
3.4
3*4
3*3
3.3
3.4
3.3
3.3
3*3
3*3
3*3
DATA READI
3*3
3*4
3*3
3*4
3*3
3*3
3*3
3*2
3.3
3.3
32. 7
31 • 1
31.7
33.3
33.0
33* 1
31*6
31*7
33. 1
^ *•* w •
33*4
33*0
35*0
33.3
35.0
59.2
33*4
33.4
NG
33.6
33.2
33*3
32.7
33.3
32*7
33.6
35*2
34*9
34*0
M3/HR
NERATOR
NITROGEN
REGEN.
VELOCITY
M/SEC
7.7
7.7
4-3
4.6
5.2
6.2
4.2
4.4
4.1
4*7
5.9
6*0
6*5
6.2
6*2
6.3
7.2
4.9
4.9
4.7
4.9
4.9
5.0
4*9
4.2
3.9
4.2
2.9
5.7
3*8
4.2
4.2
4.2
4.2
• 71
.79
• 63
• 62
•61
• 84
• 69
•61
.67
• 80
•78
• 80
• 62
• 67
.79
.86
.72
• 79
.70
.79
.87
.70
.75
.72
>68
.70
'61
77
66
70
77
77
73
- 176 -
-------
APPENDIX B: TABLE II.
RUN 5: GAS FLOW RATES
PAGE 6 OF 9
DAY.HOUR
AIR
17. 1930
17.2030
SHUT
20.2030
20 . 2 1 30
20.2230
20.2330
21 .0030
21 .0130
21 .0230
21 .0330
21 .0430
21.0530
21 .0630
21.0730
21 .0830
21 .0930
21. 1030
21. 1 130
21.1230
21. 1330
21. 1430
21 . 1530
21. 1630
21. 1730
21 . 1830
21 . 1930
21 .2030
21.2130
21 .2230
21 .2330
22.0030
22.0130
22.0230
22.0330
22*0430
403.
412*
DOWN AT
460.
443.
442.
460.
468.
467.
476.
459.
458.
458.
459.
441 .
441 .
441 •
442.
435.
434.
436.
436.
436.
436.
436.
427.
435.
384.
367.
366*
382.
382.
382.
383.
383.
383.
17
GAS
ER
E GAS
127.
127.
STONE
.2030
85.
105.
105.
105.
65.
65.
52.
74.
70.
71 .
64.
62.
59.
61 .
61 .
59.
59.
59.
57.
57.
56.
42.
96.
13.
136.
165-
165.
145.
144.
144.
144.
144.
144.
RAT
PILOT
PROPANE
3-3
3.3
CHANGE
FOR 72
3.2
3.2
3.2
3.2
3.2
3.2
3-2
3.2
3.2
3.2
3-2
3.2
3«2
3.3
3-4
3*4
3.4
3.4
3-4
3-4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.3
3.3
3.4
3.4
E S M
REG
AIR
34.3
34.6
HOURS
34. 1
36.3
37.5
37.1
36.6
33.9
35.2
35.8
34.9
34.9
34.5
34.2
34.2
34. 1
33.3
33.2
33.4
33.4
33.4
33-2
32.8
33.4
31 .2
32.0
33.3
34.7
35.3
34.7
33.4
34.0
34.0
33.7
33.8
M3/HR
NERATOR
NITROGEN
3.9
3.9
6.1
4.9
2.5
2.1
2.3
2. 1
2.1
2. 1
2.3
2.2
2.0
2.0
.9
.9
.9
.9
• 8
2.0
2.0
1.9
2.0
2.0
1.9
1.9
1.9
2.0
2. 1
2.2
2.3
2.3
1.0
1 .7
4.PI
REGEN.
VELOCITY
M/SEC
1 .73
1 .74
.75
.79
.79
.75
.74
• 61
• 6R
.70
.67
.67
.64
• 62
.62
.62
.58
.57
• 58
.59
.59
.58
.56
.58
.48
.52
.59
.66
.69
.67
.61
.64
.58
• 59
.70
- 177 -
-------
APPENDIX Bt TABLE II.
RUN 5: GAS FLOW RATES
PAGE 7 OF 9
DAY. HOUR
22.0530
22.0630
22.0730
22*0830
22.0930
22* 1030
22. 1 130
22. 1230
22.1330
22. 1430
22*1530
22. 1630
22.1730
22. 1830
SHUT
23. 1730
23.1830
23. 1930
23*2030
23*2130
23*2230
23.2330
24.0030
24.0130
24.0230
24.0330
24.0430
24.0530
24.0630
24.0730
24*0830
24.0930
24.1030
24.1130
24*1230
24*1330
24* 1430
GAS
GASIFIER
AIR
383*
374*
383.
382.
382.
383.
383*
383*
382*
383.
384.
384.
384*
384*
DOWN AT
329.
346.
346.
363*
329*
346*
347.
373.
373.
373*
373*
373*
381*
381 *
355*
381*
389*
397.
379.
363*
373*
366*
FLUE GAS
144*
144*
134*
148*
145.
145*
145*
145*
145*
145*
144*
145*
144*
144*
22*1830
185*
185.
185.
185.
175.
179.
179.
175.
175.
165.
165.
165.
155.
155.
155.
135.
145.
144*
145*
154.
164.
164*
RAT
PILOT
E S M
REG
PROPANE AIR
3*4
3.3
3*3
3*3
3*4
3*4
3*4
3*4
3*4
3*4
3*4
3*4
3*4
3*4
FOR 23
3*5
3*5
3*5
4* 1
3*5
3*5
3*5
3*5
3.5
3.5
3*5
3*5
3*5
3*5
3*5
3.5
3*5
3*5
3*5
3*5
3*5
3.5
34.2
33.4
33*2
33*7
33*1
32*3
33*3
28*8
32*7
33. 1
33.4
33.3
33*8
32*7
HOURS
34.6
34.9
34.9
34.4
33*9
33.4
32.5
32.8
33.9
33*3
32*7
33*2
33*9
33*9
33*4
32*8
32.5
32.9
33.6
33.8
34. 1
34*5
M3/HR
NERATOR
NITROGEN
2*3
2.2
2.P
2.3
2.4
1.9
2.2
2*2
2-2
2.2
2*2
2*2
2*2
2*2
2*5
2*6
2.3
2.3
2.3
2.3
2.3
2.3
2.3
2.3
2.3
2.3
2*3
2*3
2*3
2.3
2.5
2.3
2*5
2.3
2*3
2*4
REGEN.
VELOCITY
M/SEC
.64
.60
• 59
• 62
.60
• 54
• 59
• 39
.57
• 59
.60
• 59
• 62
• 56
.67
.69
• 67
• 66
*64
• 62
• 57
• 59
• 63
• 61
• 58
• 60
• 63
• 63
• 61
• 58
• 57
.58
• 62
• 63
• 65
.66
- 178 -
-------
APPENDIX Bt TABLE II.
RUN 5: GAS FLOW RATES
PAGE 8 OF 9
DAY.HOUR
GAS
GASIFIER
AIR FLUE GAS
RATES M3/HR REGEN.
PILOT REGENERATOR VELOCITY
PROPANE AIR NITROGEN M/SEC
24.1530
24.1630
24-1730
24.1830
24.1930
24*2030
24.2130
24.2230
24.2330
25.0030
25.0130
25*0230
25.0330
25*0430
25.0530
25.0630
25.0730
25*0830
25.0930
25*1030
25.1130
25.1230
25.1330
25.1430
25.1530
25. 1630
25.1730
25-1830
25.1930
25-2030
25.2130
25.2230
25*2330
26.0030
26*0130
26.0230
26.0330
26.0430
26*0530
26-0630
366.
366*
383.
365.
365.
365.
366*
366*
365.
366.
366.
366.
366.
366.
366.
366.
366.
366.
349.
366.
348*
348.
365*
366.
366*
366.
366.
366.
365.
366.
374.
374.
349.
348.
366*
357.
374-
365.
366.
366.
164.
165*
164*
155.
165.
165.
164.
164*
164*
164*
164.
164*
164.
164.
164.
164.
164.
164.
155.
155.
154.
155.
155.
155.
155.
155.
155-
165.
155-
155.
158.
158.
164.
164.
164.
164.
144*
154.
154.
154.
3.5
3.5
3.5
3.5
3.5
3.6
3.6
3*4
3*4
3.4
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3-2
3.2
3*2
3.2
3.2
3*2
3-2
3.2
3.2
3-2
3.2
3»2
3.2
3.2
3.2
3.2
3.2
3.2
3.3
3*3
34.2
34-7
34.2
33-9
33. B
35.2
34*8
35*3
35*2
38*2
35*5
35.1
35.3
35.4
35.4
35.4
35.5
35.5
35.4
35.6
35.2
34.8
34*4
31 *8
35*0
34*9
35*3
35.1
34*1
34.0
33.9
33.9
33*5
33*5
34*4
35.2
35.8
35.7
35.8
35.5
2.4
2.4
2.4
2.4
2.6
2.3
2.3
2.4
2.4
2*4
2.4
2.4
2.5
2.5
2.5
2.5
2.5
2.5
2*5
2*5
2*5
2*5
2.3
2*5
2*5
2*5
2.4
2.5
2.5
2.5
2.5
2.5
2.4
2.5
2.4
2*4
2*5
2-5
2.5
2.5
1.65
1.67
1.65
1 .64
1 .64
1 .69
1 .67
1 .70
1.69
1.83
1 .71
1 .69
1.70
1.70
1.70
1 .71
1.71
1.71
1.71
1.72
1 .70
1.68
1.65
1.54
1*69
1.69
1 .70
1.69
1.64
1.63
1.63
1.63
1.61
1 .61
1.65
1.68
1.71
1.71
1.71
1-70
- 179 -
-------
APPENDIX B: TABLE II*
RUN 5: GAS FLOW RATES
PAGE 9 OF 9
DAY.HOUR
GAS
GASIFIER
AIR FLUE GAS
RATES M3/HR REGEN.
PILOT REGENERATOR VELOCITY
PROPANE AIR NITROGEN M/SEC
26*0730
26*0830
26*0930
26*1030
26*1130
26*1230
26*1330
26*1430
26*1530
26*1630
26* 1730
26*1830
366*
357.
366*
339.
339.
348.
347.
401.
365.
366.
356*
365*
164*
160.
158*
164.
164*
160*
155.
155*
151.
151*
145*
145.
3.3
3.3
3*3
3.3
3.3
3.3
3*3
3*3
3.3
3.3
3*3
3*3
35*7
35*9
35*4
36*0
36.3
36*0
36*0
35*8
35*3
35*1
34*5
34.7
2.5
2*5
2.5
2.4
2*5
2*3
2.6
2.5
2.4
2*5
2*4
2*5
• 71
.72
.70
.71
.73
.71
• 72
.71
.69
• 6B
.65
.66
- 180 -
-------
APPENDIX B: TABLE III.
RUN 5: PRESSURES PAGE
1 OF 9
GASIFIER P. KILOPASCALS
DAY .HOUR
2*0130
2.0230
2.0330
2.0430
2*0530
2.0630
2.0730
2.0830
2.0930
2.1030
2. 1 130
2.1230
2. 1330
2. 1430
2. 1530
2*1630
2. 1730
2.1830
2. 1930
2.2030
2 . 2 1 30
2.2230
2.2330
3.0030
3.0130
3.0230
3.0330
3.0430
3*0530
3.0630
3.0730
3.0830
3.0930
3.1030
3*1130
3*1230
3.1330
3.1430
3.1530
3.1630
GAS
SPACE
4-0
3.7
4.0
4.2
4.4
4*4
4.4
4*5
4.6
4.0
4.0
4.0
3*6
4.0
4*0
4*0
3*5
3.5
3.6
3.9
3.4
3*4
3*6
3.5
3*6
3.5
3.5
3.5
3.7
3.7
3*6
3*6
3.7
4.0
3.9
3.9
3.7
4.0
DISTRIB
D.P.
3.5
3*5
3.7
4.0
4*0
4*0
4*0
MISSED
4*0
4.0
4.0
4*0
4*0
3.9
3*9
3*7
3.7
3.1
3>1
3-1
3.5
3*0
3*1
3*1
MISSED
3*5
3*6
3.5
3*0
3-0
3.0
3.0
3.0
3*2
3*5
3*0
3*5
3*5
3*2
3*2
BED
D.P*
4*7
5*0
4-7
4.6
4.6
4.6
4*5
DATA READI
4*6
4*6
4.7
4.7
4.7
4*7
4*7
4-7
4.9
4.7
4.7
5*0
4.7
4.9
4*9
4*9
DATA READI
5*0
5.1
5.2
5.2
5.2
5*2
5.2
5.4
5.4
5*2
5*4
5.2
5.4
5.5
5.0
GASIFIER
BED
SP. GR.
0.70
0.70
0.70
0.70
0.80
0.75
0.75
NG
0.75
0*80
0.70
0.80
0.80
0.80
0.70
0.75
0.75
0.80
0.80
0.80
0.75
0.85
0*85
0.80
NG
0*80
0.80
0.85
0.80
0.85
0.85
0.85
0.80
0.85
0*85
0*85
1.00
1.00
0.80
0.75
REGEN.
BED
D.P.
4.7
5.7
6.2
6.7
7.0
7.5
8.0
8.0
8.2
8.0
7.0
8.3
8.5
7.0
7.0
7.0
7.0
7.0
5.0
5.0
5*0
5.0
5*0
5.0
5-0
5.0
5.0
5.1
5.7
5.7
5.5
5-2
6.2
6.7
6.0
6.5
6.7
6.5
- 181 -
-------
APPENDIX B: TABLE III .
RUN 5J PRESSURES PAGE
OF 9
DAY. HOUR
3. 1730
3* 1830
3* 1930
3*2030
3*2130
3.2230
3.2330
4.0030
4.0130
4.0230
4.0330
4.0430
4.0530
4*0630
4*0730
4.0830
4 . 09 30
4. 1030
4.1 130
4. 1230
4.1330
4.1430
4.1530
4.1630
4.1730
4.1830
4.1930
4.2030
4.2130
4.2230
4.2330
5.0030
5.0130
5.0230
5.0330
5.0430
5.0530
5*0630
5.0730
GASIFI
GAS
SPACE
4.
4.
4.
4*
4.
4.2
4.1
4.2
4.1
4.0
4.4
4.5
4.5
4.7
4.9
4.9
5*5
5*5
5*5
5.1
5.2
5.1
5.2
5.2
5.2
5.2
5.2
5.4
5.2
5.1
5.1
5.1
5.0
5.1
5.2
5*2
5.4
ER P. KI
DISTRI
D.P*
3.5
3.5
3.2
3.4
3.5
3.4
3*4
3.4
STONE
3.2
3.2
3.4
3.4
3.4
3.4
3.4
3.4
3.7
3.7
3.7
3.7
MISSED
4*0
4.0
4.0
4.0
4.0
4.2
4.2
4.2
4.2
4*4
3.9
MISSED
3.9
3.7
4.0
4.7
4.2
4*4
LOPASCALS C
B. BED
D.P.
4.7
4*5
4-5
4.5
4.5
4.5
4.5
4.5
CHANGE
4.5
4.5
4.4
4.4
4.8
4.2
4.7
4.8
4.5
4.5
4.5
4.4
DATA READING
4.5
4.5
4.5
4*5
4.5
4.5
4.5
4.5
4.5
4.5
4.5
DATA READING
4.5
4.5
4.5
4.5
4*4
4.5
3ASIFIER
BED
SP. GR.
0.80
0.70
0.80
0.80
0.80
0.80
0.90
0.80
0.80
0.80
0.80
0*80
0.75
0.75
0.75
0.75
0*80
0.80
0*80
0.80
0.70
0.70
0.70
0.70
0.70
0.70
0.70
0.70
0*70
0.65
0.65
0.65
0.65
0.65
0.60
0.60
0.60
REGEN.
BED
D.P.
7.0
6.5
6. 7
7.0
6.7
6.7
6.7
6.7
7.0
6.7
6.R
6*8
7.0
6. 7
• r
6. 7
tf • I
6. 7
4. 5
4* 5
4* 5
4* 5
4* 5
~ w *»/
4*5
4* 5
4.5
4.5
4*5
4.5
4.7
5.0
5.2
5.0
5.2
5.2
5.0
4.7
5.5
5.2
- 182 -
-------
APPENDIX B: TABLE III.
RUN 5: PRESSURES PAGE
3 OF 9
GASIFIER P. KI
DAY. HOUR
5.0830
5.0930
5.1030
5.1130
5.1230
5*1330
5.1430
5.1530
5*1630
GAS
SPACE
5.2
5.1
5-1
5.0
4.9
5.1
5.1
5.2
DISTRI
D.P.
4. 1
4.0
4.0
4.2
4.5
MISSED
3.9
3.9
3.9
LOPASCALS
B. BED
D.P.
4.5
4.5
4.5
4.5
4.5
DATA READI
4.4
4*4
4.4
GASIFIER
BED
SP. GR.
0.60
0.60
0.60
0.60
0.60
NG
0.60
0.65
0.65
REGEN
BED
D.P.
5.5
5.2
5.5
5.7
5.7
5.7
5-5
5.5
5.0830
5.0930
5.1030
5.1130
5.1230
5*1330
5.1430
5.1530
5*1630
SHUT
6.0230
6.0330
6*0430
6.0530
6.0630
6.0730
6.0830
SHUT
8.2230
8.2330
9.0030
9.0130
9.0230
9.0330
9.0430
9.0530
SHUT
1 1*1430
11*1 530
11*1630
1 L1730
5.2
5.1
5-1
5.0
4.9
5.1
5.1
5.2
DOWN AT
6.3
6.0
6.3
6.2
6*5
7.0
6*7
DOWN AT
3*2
3.4
3*3
3*2
3*2
3*2
3*2
3*2
DOWN AT
3*9
3*9
3*7
3.7
5*1630 FOR 10 HOURS
3.
3-
3.
3
6
7
6
6
3*6
3.5
2.9
3.9
4*1
4.2
4*4
4.5
4*5
4.5
6.0830 FOR 62 HOURS
4.0
4.2
4*2
4.2
4.2
4.2
4*2
4.2
4.6
4.6
4.7
4.9
5.0
5*0
5*0
5*0
9.0530 FOR 57 HOURS
0.
0<
0.
0.
4*5
4*6
4*9
4*9
0.70
0.65
0.67
0.67
0.65
0*70
0.65
0.85
0.75
0.75
0.75
0.75
0*70
0.80
0.75
0.65
0.65
0.70
0.70
5.0
5.5
5-2
5*7
5.0
5.7
6.0
0.
0.
0.
0*
0.
0*
0*
0*
4*4
4.7
4.9
4.7
- 183 -
-------
APPENDIX B: TABLE III.
RUN 5: PRESSURES PAGE
4 OF 9
GASIFIER P. KI
DAY. HOUR
1 .1830
1 • 1 9 30
1 .2030
1 .2130
1 .2230
11.2330
12*0030
12.0130
12*0230
12*0330
12*0430
12.0530
12.0630
12*0730
12*083(9
12*0930
12* 1030
12. 1 130
12*1230
12.1330
12.1430
12*1530
12. 1630
12. 1730
12.1830
12.1930
12.2030
12.2130
12.2230
12*2330
13*0030
13.0130
13.0230
13*0330
13*0430
13*0530
13.0630
GAS
SPACE
3.9
3.7
4.0
3.9
4.0
4.0
4.0
4. 1
4-1
4* 1
4.0
4.0
4.0
4.1
4.0
3*7
3.9
3*7
3.7
3.7
3.7
3.7
3.9
3.9
4.0
4.0
4.2
4.2
4.2
4.2
4.2
4.2
4.2
4.2
4.2
DISTRI
D.P.
0.
0.
0.
0.
0.
0.
5.2
MISSED
5.2
5.2
5.2
5.2
5.0
5.2
5.2
5.1
4.6
MISSED
4.4
4.6
4.5
4.7
4.7
4*7
4*9
5.0
5*2
5.4
5*7
5.7
5.8
5.6
5*6
5.6
5.7
5.6
5.6
LOPASCALS GASIFIER
B. BED
D.P.
5.4
5.5
5.5
5-5
5.4
5.4
5.4
DATA READING
5.2
5.5
5*2
5.4
5.2
5.2
5.2
5.5
5.5
DATA READING
5.5
5.5
5.5
5.7
5*5
5.5
5*5
5.2
5.0
7.6
4.5
4.5
4.5
4.6
4.6
4*6
4.5
4.5
4.5
BED
SP. GR.
0.70
0.70
0.70
0.70
0*70
0*70
0.70
0.70
0*70
0.70
0.80
0.70
0.70
0.70
0.70
0.70
0.75
0.70
0.70
0.70
0.70
0.70
0.70
0.70
0.70
0.70
0.65
0.65
0.67
0.67
0.67
0.67
0.67
0.67
0.67
REGEN.
BED
D.P.
5.7
5*5
5*7
5.5
5*0
5.0
6.0
5.5
5*0
5*0
5.0
5-0
5.2
5.5
5.5
5.5
6-0
6.0
5.7
6.2
6.2
6.0
6.2
6.0
5.5
5.7
5.7
4.7
6. 1
5.4
5.7
5.5
5.6
5.5
5.6
- 184 -
-------
APPENDIX B: TABLE III.
RUN 5: PRESSURES PAGE 5 OF 9
GASIFIER P. KILOPASCALS GASIFIER REGEN,
DAY.HOUR GAS D1STRIB- BED BED BED
SPACE D.P* D.P. SP* GR. D.P.
SHUT DOWN AT 13.0630 FOR 73 HOURS
16.0730
16.0830
16.0930
16* 1030
16. 1 130
16.1230
16.1330
16.1430
16*1530
16*1630
16.1730
16.1830
16.1930
16.2030
16.2130
16.2230
16.2330
17.0030
17.0130
17.0230
17.0330
17.0430
17.0530
17.0630
17.0730
17.0830
17.0930
17.1030
17. 1 130
17. 1230
17. 1330
17* 1430
17.1530
17. 1630
17. 1730
17.1830
4.2
4.0
4.0
4.0
4.0
4.0
4.0
4*0
4.0
4.0
4.0
4.2
4.2
4.2
4.2
4.2
4.4
4*4
4.4
4.4
4.4
4*5
4*4
4*4
4*4
4*4
4*4
4.4
4.4
4.4
4*4
4*4
4.4
4.4
5.1
4.9
5*0
5.1
5.5
5.1
5.0
MISSED
5.0
4.7
4.7
4.9
4.7
5.0
5.0
5- (3
4.7
5.0
5.0
5.0
4.9
5.0
5.0
4.9
4.9
MI SSED
5.0
4.9
4.9
4.7
4.7
4.7
4.7
4.7
4.5
4.6
4.2
4.5
4.9
4*9
5*0
5.2
5.2
DATA READING
5.6
5.7
5.7
5.5
6.0
6.1
8.5
6.2
6.2
6.0
6.2
6.0
6.0
6.0
6.0
6*2
6*1
DATA READING
6.2
6.2
6.2
6-2
6*2
6.2
6.2
6*2
6.5
6.5
0.75
0.75
0.75
0.70
0.70
0.70
0.70
0*65
0.70
0.70
0.70
0.65
0.60
0.65
0.65
0.65
0.65
0.65
0.65
0.65
0.65
0.65
0.65
0.65
0.65
0.65
0.70
0.70
0.70
0.70
0.70
0.70
0.70
0.70
6.5
4.5
3-7
5.0
4.5
5*0
5.2
5.6
5.5
5.7
5.2
5.7
5.1
5.7
5.7
5.2
5.0
5-2
5.5
5.7
5*7
5.7
6*0
5*7
6*0
6* 5
6.2
6*0
6*0
6-2
5.2
5*8
5.8
5.2
- 185 '-
-------
APPENDIX B: TABLE III*
RUN 5: PRESSURES PAGE
DAY. HOUR
17. 1930
17.2030
SHUT
20.2030
20*2130
20.2230
20.2330
21 .0030
21.0130
21.0230
21.0330
21.0430
21.0530
21 .0630
21.0730
21.0830
21.0930
21.1030
21.1130
21.1230
21.1330
21*1430
21 . 1 530
21.1630
21.1730
21.1830
21.1930
21.2030
21.2130
21.2230
21.2330
22.0030
22.0130
22.0230
22.0330
22.0430
GASIFI
GAS
SPACE
4*4
4.4
DOWN AT
5-5
5.5
5.6
5.7
5.8
6*0
6.0
6.1
6.1
6.1
6.2
6*3
6.2
6.5
6.3
6*3
6.2
6*3
6.3
6.5
6*6
6.7
6.8
7.0
6. 1
6*2
6.1
6.1
6.2
6*2
6.3
6.3
6*5
ER P. KILOPASCALS GASIFIER
DISTRI
D.P*
4.6
4.6
STONE
17.2030
4.8
5.1
4.7
4.7
4.5
4.4
4.4
4.5
4.5
4.5
4.5
4>4
4*2
4.1
4*2
4.2
4*
4.
4.
4.0
4.
4*
4.2
4.0
4.4
4.7
4.7
4.7
4.7
4.7
4.7
4.7
4.7
B* BED
D.P.
6.5
6.5
CHANGE
FOR 72 HOURS
4.8
5*0
5.1
5.0
5.1
5.1
5-2
5.2
5.5
5.5
5.5
5-5
5.5
5.5
5.6
5.5
5.6
5.5
5.5
5.7
5*6
5*6
5.7
5.6
5*4
5.5
5.5
5*4
5.5
5.7
5.6
5.7
5.7
BED
SP. GR-
0.70
0.70
0.73
0.75
0.70
0.75
0.70
0.75
0.70
0.70
0.75
0*80
0.75
0.75
0.80
0.75
0.75
0.80
0.75
0*80
0.80
0.75
0.75
0.75
0.75
0.80
0.75
0.80
0.75
0.80
0.75
0.80
0.75
0.75
0*80
6 OF 9
REGEN,
BED
D.P.
5.7
6.0
5.8
6*2
6.2
6.0
6.0
6.5
6.5
6.7
6.5
6.7
6.7
6.7
6.7
6.7
6.7
6.5
6*2
6.5
5.7
5.7
6*2
7.2
6.0
5.5
6.2
5.7
5.7
6.0
6.7
6.2
6.2
6.2
6.0
- 186 -
-------
APPENDIX B: TABLE III.
RUN 5: PRESSURES PAGE
DAY.HOUR
GASIFIER P. KILOI
GAS DISTRIB.
SPACE D.P.
22.0530
22.0630
22.0730
22.0830
22.0930
22.1030
22 .11 30
22.1230
22. 1330
22.1430
22.1530
22. 1630
22.1730
22.1830
SHUT
23. 1730
23.1830
23.1930
23.2030
23.2130
23.2230
23.2330
24.0030
24.0130
24.0230
24.0330
24.0430
24.0530
24.0630
24.0730
24.0830
24.0930
24*1030
24.1130
24*1230
24.1330
24*1430
6.5
6.5
6.7
6.6
6*6
6.5
6*6
6.6
6*6
6.6
6.6
6.6
6.7
6.8
DOWN AT
5.2
5.4
5.2
5.2
5.1
5*2
5.4
5.4
5.5
5.5
5.6
5.5
5.5
5.6
5.5
5.7
6.0
6.0
5.7
5.6
5.5
5.6
4.7
4.7
4.7
4.9
4.9
4.9
4.9
4.9
4.7
4.7
4.7
4.7
4.7
4.7
22*1830 FOR
6.0
6.0
6.0
6.0
5.8
6.0
6.1
6.2
6.2
6.2
6.2
6.2
6. 1
6. 1
6.1
6.3
6.2
6.2
6*2
6*1
6.3
6.3
iCALS GASIFIER
BED
D.P.
5.7
5.7
5.7
5.7
5.7
5.7
5.8
5.8
6.0
6.0
6.0
6.0
6.0
6.0
23 HOURS
4.6
5.0
5.2
5.4
5.5
5.7
5.7
5.5
5.7
6*0
6.0
6.0
6.0
6.0
6*0
6.0
6.1
6-3
6*3
6.2
6.3
6.2
BED
SP. GR.
0.80
0.80
0.75
0.80
0.80
0.75
0.80
0.80
0.80
0.80
0.80
0.80
0.80
0.80
0.70
0.70
0.70
0.70
0.70
0.70
0.70
0.70
0.70
0.65
0.70
0.70
0.70
0.70
0.70
0.70
0.70
0.70
0.75
0.70
0.75
0.75
7 OF 9
REGEN.
BED
D.P.
6.2
6.2
6.2
6.2
6*2
6.5
6*5
6.5
5.7
6.0
6.2
6*2
6.2
5.5
5
5
5
5
5
5
6
0
5
7
7
5
5
0
5.5
6.0
6*0
6.0
6*0
6.0
6*0
6.0
6.0
6.0
6.0
6*0
6.0
6.0
6*0
- 187 -
-------
APPENDIX B: TABLE III.
RUN 5: PRESSURES PAGE
8 OF 9
GASIFIER P. KILOPASCALS GASIFIER
DAY.HOUR GAS DISTRIB. BED BED
SPACE D.P. D.P. SP. GR.
REGEN.
BED
D.P.
24. 1530
24. 1630
24-1730
24. 1830
24.1930
24.2030
24.2130
24*2230
24.2330
25*0030
25*0130
25.0230
25.0330
25.0430
25.0530
25*0630
25.0730
25*0830
25.0930
25. 1030
25*1130
25* 1230
25. 1330
25*1430
25. 1530
25.1630
25.1730
25. 1830
25.1930
25.2030
25.2130
25.2230
25.2330
26.0030
26.0130
26.0230
26.0330
26.0430
26*0530
26.0630
5.5
5.5
5.6
5.6
5.7
5.7
5-7
5.7
5*8
5.8
5.7
5*8
5*8
5.9
6.0
5.8
5.8
6.0
6.0
6*0
5*8
5.8
5.8
6.0
5.8
5.7
5.7
6*1
6.2
6.3
6.2
6.2
6.2
6*2
6.2
6*3
6. 2
6.3
6*3
6.3
6*3
6.2
6.2
6.2
6.5
6.7
6.7
6.7
6.7
6.7
6.7
6.7
6.7
6.7
6.7
6*7
6.7
6.7
6*7
6.7
6.7
6.7
6.7
6*7
6*7
6.7
6.7
7*2
7.2
7.2
7.3
7,2
7.3
7*2
7*2
7.2
7.2
7.0
7.1
7.1
6. 1
6. 1
6.0
6.2
6.2
6.2
6.2
6.5
6.2
6.2
6*2
6*2
6.3
6.3
6.2
6.2
6.2
6.2
6.3
6.0
6*0
6.5
6*3
6.3
6.3
6.5
6*5
6.3
6.2
6.2
6.1
6*2
6*2
6.2
6*2
6*2
6*2
6.2
6.2
6.2
0.75
0.75
0.70
0.70
0.70
0.70
0.70
0.70
0.70
0.70
0.70
0.70
0.70
0*70
0*70
0.70
0.70
0.70
0.70
0.70
0.70
0.75
0.70
0.70
0.70
0*60
0.70
0*70
0.65
0.65
0.65
0.67
0.67
0.70
0.70
0.70
0.70
0.70
0.70
0.70
6.0
6.0
6.0
6.0
6.0
6.0
6.0
6.5
6.7
6.7
6.7
6.8
7.0
7.0
7.0
7.0
7.0
7.0
7.0
6.5
6.5
6*2
6.2
6.0
6.0
6.5
6.5
7.0
6.2
6.2
6.2
6.0
6.2
6*2
6.2
6.0
6.0
5.7
5.7
6.0
- 188 -
-------
APPENDIX Bt TABLE III
RUN 5: PRESSURES
PAGE 9 OF 9
GASIFIER P. KILOPASCALS
DAY. HOUR
26.0730
26.0830
26.0930
26.1030
26.1130
26.1230
26.1330
26.1430
26.1530
26.1630
26* 1730
26.1830
GAS
SPACE
6.3
6.3
6.5
6.5
6.5
6.5
6.5
6.5
6.5
6.7
6.6
6.6
DISTRIB.
D.P.
7.1
7.1
7.1
7.1
7.1
7.0
7.0
7.0
7.0
7.0
7.0
7.0
BED
D.P.
6.2
6.2
6.2
6.2
6.1
6.2
6.1
6.2
6*3
6.3
6.3
6*2
GASIFIER
BED
SP* GR.
0.70
0.70
0.70
0.65
0.65
0.65
0.65
0.65
0.65
0.65
0.65
0.65
REGEN
BED
D.P.
6.2
6.2
6.5
6.6
6.6
6.6
6.7
7.0
5.7
6*2
6.5
6.5
- 189 -
-------
APPENDIX
RUN 5s DESULPHURISATION
Bl TABLE IV.
PERFORMANCE PAGE 1 OF 9
DAY. HOUR
2 . 0 1 30
2.0230
2.0330
2.0430
2.0530
2.0630
2.0730
2.0830
2.0930
2*1030
2 . 1 1 30
2. 1230
2.1330
2*1430
2.1530
2.1630
2. 1730
2. 1830
2. 1930
2*2030
2.2130
2.2230
2.2330
3.0030
3.0130
3.0230
3.0330
3.0430
3*0530
3.0630
3.0730
3.0830
3.0930
3.1030
3.1130
3.1230
3.1330
3*1430
3*1530
3* 1630
SULPHUR GAS
REMOVAL VEL.
% M/S
84.5
83.0
74.8
81 .0
95.9
97.8
69* 1
46.9
45.1
63*9
64.5
58.2
63.9
66.7
70.3
75.0
74.3
76.2
75.6
76.2
69.9
69.9
70.5
69*6
70.8
71.4
70.7
73.0
71.7
77.5
79.5
72.7
75.9
75.0
77.5
68.5
72.5
74.4
.56
,55
.65
.68
.66
.63
.66
.64
.74
2.06
.62
• 65
.62
• 64
• 66
.60
*42
• 42
.45
• 64
• 67
• 45
• 43
.41
• 41
.41
• 40
• 36
• 36
• 37
• 36
• 38
•48
• 45
• 42
.45
• 45
• 38
G-BED
DEPTH
AIR/
FUEL
CENTIM Z ST.
68*
72.
68.
67.
58*
62.
60.
MISSED
62.
58.
68.
60.
60.
60.
68.
64*
66 •
60.
60.
63.
64.
58.
58.
61.
MISSED
63.
65.
62.
66.
62.
62.
62.
68.
64.
62*
64.
53.
54.
69.
67.
23*2
23.3
22.2
22.9
23.0
23. 1
23.5
CAO/S
RATIO
MOL-
2.46
2.04
0.74
0.
0.19
0. 19
0*14
X CAS
TO CAO
24*4
32*5
46*4
36.4
46* 1
39.6
34* 1
REGEN.
S OUT *
OF FED
25.5
36.4
42.0
34.6
49. 5
37.5
28.4
DATA READING
24.3
21.7
20.3
20.4
21*5
20.8
20.6
20.5
20.5
19.2
19.2
20.0
19.9
18*8
19.9
20.9
0*27
0*35
0*41
0*39
0*45
0*52
0*55
0*58
0*55
0.66
0.66
0.59
0.59
0.59
0.65
0.76
23.4
33*0
26*3
15*7
37.5
50*0
43*6
43.3
39.8
49.4
49.4
19.4
37*6
44*9
42.7
35.4
20.6
31 .4
25.0
15. R
39.4
54.4
46.2
45- 1
41.8
48.2
48*2
18.5
29. 1
47. 1
49.7
39.7
DATA READING
19.8
20.7
20.3
19.9
20.1
20.3
20.2
21.1
20.0
20.9
21.2
19.9
20.3
20.7
20.9
0.65
0.71
0.63
0.59
0.52
0.62
0.62
0.67
0.49
0.43
0.43
0.45
0.54
0.53
0.48
50.6
40.2
40.0
33.1
33.4
38.8
38*5
4]. 3
35.2
19.4
29.8
8.9
44.8
29.8
35.4
58.0
47. 1
46* 1
38.6
38*4
44. 5
44. 1
46.5
38*0
20.3
32* 1
9*3
47.5
33.0
40. 4
- 190 -
-------
/ APPENDIX B: TABLE IV.
RUN 5: DESULPHURISATION PERFORMANCE PAGE 2 OF 9
DAY. HOUR
3 • 1 7 30
3.1830
3. 1930
3.2030
3*2130
3.2230
3.2330
4.0030
4.0130
4.0230
4.0330
4.0430
4.0530
4.0630
4.0730
4.0830
4.0930
4. 1030
4. 1130
4.1230
4. 1330
4. 1430
4*1530
4.1630
4-1730
4. 1830
4. 1930
4*2030
4.2130
4.2230
4.2330
5*0030
5.0130
5.0230
5.0330
5.0430
5.0530
5.0630
5.0730
SULPHUR
REMOVAL
*
66.6
65.5
58«7
56.4
57.6
59.7
52.2
44.0
70.1
69.6
70.9
71 .4
90.5
73.8
83.2
62.4
-
76.4
-
62.3
95.5
75.6
72.8
81-8
94.0
90.2
-
-
-
86*9
88>4
90.7
98.7 .
90.0
88.0
93-3
96*5
GAS
VEL.
M/S
1.47
1*45
1*50
1.44
1.52
1 .60
1.55
1.56
1.42
1.37
1.42
1.46
1.29
1.30
1 .36
1 .43
1 .38
1.37
1.43
1.45
1.54
1*56
1.55
1 .53
1.53
1 .53
1.55
1.64
1.63
1*42
1 .46
1.50
1.50
1 .49
1.58
1.55
1.52
G-BED
DEPTH
AIR/ CAO/S REGEN.
FUEL RATIO X CAS S OUT %
CENTIM % ST. MOL. TO CAO
60.
65.
57.
57.
57.
57.
50.
57.
STONE
57.
57.
55.
55.
57.
57.
64.
65.
57.
57.
57.
55.
MISSED
65.
65.
65.
65.
65.
65.
65.
65.
65.
70.
70.
MISSED
70.
70.
70.
76.
74.
76.
21 .9
19.7
22.0
18*3
20.2
20.2
20.1
21 .0
CHANGE
19.6
19.8
20.7
20.3
19.2
20.3
20.1
20.4
20.6
19.4
19.3
19.7
DATA READI
21*0
2L2
21.8
81-5
21.2
21.0
21.2
21*2
21 .3
21 .2
19.7
DATA READI
21.5
20.7
19.3
20.8
20.9
21.2
0.61
0.65
0.63
0.57
0.69
0.43
0.
0*
0.
0.
0.
0.
2.73
3.65
2.97
1.53
0.52
0.
0.
1 .34
NG
1 .73
1.77
1.71
1.67
2.14
2.31
2.11
.62
.65
.77
.91
NG
• 82
.79
.74
.72
.70
.35
34.2
39.5
39.8
10.9
11.3
41 .2
12.7
34.5
43.2
50.5
40. 1
40.0
-
25.7
51.0
45.9
37.8
49.8
53.4
32.3
53.6
41.5
35.3
25.6
52.7
51.0
48*0
55.7
52.2
46.2
55.0
16.2
10.3
42.4
35.0
41.8
40.3
OF FED
32.5
39.9
41 .6
10.6
8.6
43*4
1 4.4
41 .2
46.4
58.6
47.5
46-6
-
26.9
57.1
53.1
45.9
56. 1
63-7
32.1
54.2
45.4
36*1
27.4
58.6
48*4
53.5
62.7
57.4
53.8
61 .8
17.9
10.8
45.0
37.9
45. 1
44.5
- 191 -
-------
APPENDIX
RUN 5: DESULPHURISATION
B: TABLE IV.
PERFORMANCE
PAGE 3 OF 9
DAY. HOUR
5.0830
5.0930
5. 1030
5. 1 13PI
5.1230
5.1330
5. 1430
5.1530
5. 1630
SULPHUR GAS
REMOVAL VEL.
% M/S
94-7
93-4
93.4
94.2
90.9
88.5
92.9
94.8
.52
.50
.50
• 39
.38
.43
.44
.42
G-BED
DEPTH
AIR/ CAO/S REGEN.
FUEL RATIO * CAS S OUT %
CENTIM I ST. MOL. TO CAO
76.
76.
76.
76.
76.
MISSED
74.
68.
68.
20.9
20.8
20.9
20*3
19.4
DATA READI
20*4
21 .0
20.6
1 .75
2.26
1 .83
1 .73
1 • 14
NG
0.83
0.81
0.98
44.8
53.6
48.2
51.9
45.8
50.9
48.6
44.2
OF FED
47.4
55.8
51 .2
54.3
51.7
56.6
55.8
45.5
SHUT DOWN AT 5.1630 FOR 10 HOURS
6.0230
6.0330
6.0430
6.0530
6.0630
6.0730
6.0830
75.8
83.3
88.2
93.3
98. 1
96.2
98. 1
.58
• 55
.46
.54
.42
.42
• 30
56*
64.
64.
66.
70.
65*
70.
20.1 f
19.9
19.7
20.1
19.8
20.7
18.7
9*91
.39
.32
• 30
. 13
• 10
.20
38.0
44.8
31.8
43.7
52. 1
48.4
59.9
38.7
42,5
31 • 1
38.5
48.2
46.0
58.6
SHUT DOWN AT 6.0830 FOR 62 HOURS
8.2230
8.2330
9.0030
9.0130
9.0230
9.0330
9.0430
9.0530
74-2
74-2
76.9
77.4
88.3
91 .3
87.3 1
80.9 1
.50
.47
.46
.40
• 42
• 44
• 45
.42
55.
62.
64.
66.
67.
72.
63.
67.
21.8
21.4
22.0
20.7
21.0
21 .5
21.6
21 .2
1 .53
1 .56
2.00
2.03
1 .82
1 *62
1 • 19
0.93
„
5.7
14.7
15.0
27.0
33.2
—
7.0
18. 7
20.0
40.3
51.9
SHUT DOWN AT 9.0530 FOR 57 HOURS
1 1 . 1430
1 1.1530
1 1 . 1630
11*1730
73.7
82.4
82.3
82.5
1.58
1 .46
1 .46
1 .47
70.
72.
70.
71.
21.1
20.0
21.0
21.0
2.39
2. 18
0.96
0.96
25.2
12.3
32.3
20.5
29.2
13.6
41.0
25.8
- 192 -
-------
APPENDIX
RUN 5: DESULPHURISATION
B: TABLE IV.
PERFORMANCE
PAGE 4 OF 9
DAY. HOUR
1 .1830
1 .1930
1 .2030
1 .2130
1 .2230
1 .2330
12.0030
12.0130
12*0230
12.0330
12.0430
12.0530
12.0630
12.0730
12.0830
12-0930
12.1030
12. 1 130
12.1230
12*1330
12*1430
12*1530
12*1630
12. 1730
12. 1830
12*1930
12*2030
12.2130
12.2230
12.2330
13*0030
13*0130
13*0230
13.0330
13.0430
13.0530
13*0630
SULPHUR GAS
REMOVAL VEL.
X M/S
93.1
95.8
91.5
80.3
83-8
74*7
72*0
81 .2
78.8
80*7
8L4
71 .4
77*3
78*8
81*2
82.0
80.8
83.8
84*2
83.1
83.5
83.7
84-7
83.9
82*3
80.0
76.4
77.7
81 .0
80.2
84*3
80.2
87.1
89.4
87*3
• 44
.49
.46
• 55
.54
.47
• 53
.48
.47
.47
.47
• 50
• 44
.43
• 38
• 38
.39
.38
.38
• 32
• 38
.36
.40
• 40
• 44
• 46
.52
.50
.48
• 48
• 49
• 55
.55
.50
• 49
G-BED
DEPTH
AIR/ CAO/S REGEN.
FUEL RATIO X CAS S OUT X
CENTIM X ST. MOL. TO CAO
78.
79.
79.
79.
78.
78*
78*
MISSED
76.
79.
76.
68*
76.
76-
76.
79*
79*
MISSED
74.
79.
79.
83*
79.
79.
79.
76.
72*
110*
70*
70.
68.
70.
70.
70.
68.
68.
68*
21*1
21*8
21.8
21 .7
20.7
20.7
20.9
DATA READI
21 .2
20.8
20.0
20.6
19-8
20.0
20.5
21.1
20.5
DATA READI
20.3
20.4
20.3
20.3
20*2
20.2
20.3
20*2
20*3
20.3
20.1
19.6
20.4
20.1
20.2
19.9
20.1
20.2
20.4
.05
• 05
.07
.21
• 14
.25
1 .41
NG
1 .03
0.74
0.62
0.82
0*90
0.66
0.96
1.34
1 .23
NG
1.15
1 . 12
1 . 13
1 .28
1 .22
0.93
1 .07
1.15
1*04
1* 14
1.06
0.95
1 . 16
1.11
0.94
0.94
0.95
0.77
0.92
43.2
31 *9
46.6
36. 1
44.2
49.2
56*8
40.3
51.7
51.6
37.2
45*2
44.0
43*1
40. 1
37.4
31.9
42.8
35.2
45*7
33.6
46.7
37.8
41 .5
41 .5
36*4
40.8
41 .0
39.9
39*6
46* 1
39.8
41.3
44.6
37.6
OF FED
57.3
41 .0
60.8
48.2
56. 1
55.6
67.7
47.5
57.4
66.3
43.3
53.6
59.7
55.9
50.4
46.3
37.9
53.0
42.4
57.1
39.4
57.3
46.3
52.0
52.1
43-3
53.2
50. 1
47.6
48*6
58.7
50.2
52.3
58.0
49.0
- 193 -
-------
APPENDIX
RUN 5: DESULPHURISATION
B: TABLE IV.
PERFORMANCE PAGE 5 OF 9
DAY.HOUR
16.0730
16.0830
16.0930
16.1030
16.1130
16*1230
16.1330
16.1430
16.1530
16.1630
16.1730
16.1830
16.1930
16.2030
16.2130
16*2230
16.2330
17.0030
1 7 . 0 | 30
17.0230
17.0330
17.0430
17.0530
17.0630
17.0730
17.0830
17.0930
17.1030
17.1130
1230
1330
1430
1530
1630
17.
17.
17.
17.
17.
17.1730
17.1830
SULPHUR GAS
REMOVAL VEL.
% M/S
SHUT DOWN AT 1
64.9 0.90
63.7 0.96
67.5
72.7
74.7
68.0
73.6
74.8
74.2
75.0
77.7
95.4
98.0
98.7
98.7
98.6
98.0
95.6
95.6
95.7
78.3
82*8
90.3
96.8
87.8
83.3
79.3
80.0
82.9
70.8
72.4
85.6
71 .8
80.4
.56
.53
• 53
• 52
.47
• 45
• 35
• 37
• 41
• 34
• 32
• 33
• 34
• 35
• 37
.38
.37
.37
• 37
.35
• 37
• 37
• 37
.36
.32
• 30
.28
• 37
• 37
.32
.33
• 31
G-BED AIR/
DEPTH
CENTI
3.0630
57.
60.
66.
70.
72.
76.
76.
MISSED
87.
83.
83.
79.
93.
103.
132.
97.
97.
93.
97.
93.
93.
93.
93.
97.
95.
MISSED
97.
97.
90.
90.
90.
90.
90.
90.
94*
94.
FUEL
M X ST.
FOR 73
20.6
20.5
21.1
21.2
21.2
21.3
22*4
CAO/S
RATIO
MOL.
HOURS
1 .09
1 .56
1.53
1.36
1.26
1 .69
1 .77
% CAS
TO CAO
—
12.9
.
38.3
31.8
31.4
43.3
REGEN.
S OUT %
OF FED
—
13.3
41 .5
34.7
38.3
52.1
DATA READING
22.9
22.2
22.4
22.5
22.0
21.6
20*8
20.7
21*2
21.5
23.3
23.4
23.3
22.3
24.9
23.3
23.4
1.70
1-84
1-98
2. 18
2.12
2.08
1 .96
1.98
0.93
0.98
0.89
0.92
1 .08
0.77
1*28
1.08
1.11
30*4
39.9
48.4
51 .0
42.9
52.9
15.8
42. 1
34.2
37.6
45* 1
41 .1
_
41.5
39.7
39.7
41 .7
35.7
45.7
57.7
62.6
51 .3
66.5
15.1
43.8
38.0
43.6
52.7
51 .0
48.6
84.7
45.0
49.0
DATA READING
21.5
21.6
20.6
21 .3
20*8
21.5
22.4
21 .4
22.3
21*8
0.41
1.25
1.02
1*00
1.19
1*31
1 .88
1 *84
1 .33
1.17
42.3
42.4
50.3
47.2
47.5
48.1
41 .9
22.9
36.8
53.8
48.7
47.3
58.4
52.9
54.4
49.2
47.7
27.5
43.2
58.4
- 194 -
-------
RUN 5:
APPENDIX B: TABLE IV.
DESULPHURI SATI ON PERFORMANCE PAGE
6 OF 9
21
21
21
21
21
21
21
20.2030
20*2130
20.2230
20.2330
21.0030
21*0130
21.0230
• 0330
.0430
.0530
.0630
.0730
.0830
.0930
21 .1030
21.1130
21.1230
21.1330
21•1430
21.1530
21.1630
• 1730
> 1830
• 1930
.2030
21 • 21 30
21.2230
21.2330
22.0030
22.0130
22.0230
22.0330
22.0430
21
21
21
21
SULPHUR GAS
REMOVAL VEL.
X M/S
83.8 1.29
90.8 1.31
G-BED AIR/
DEPTH FUEL
CENTIM
94.
94.
X ST.
21 .3
21 .8
CAO/S
RATIO X
CAS S
MOL. TO CAO
1.09
0.98
41.5
46.0
REGEN.
OUT %
OF FED
48.7
50.2
STONE CHANGE
SHUT DOWN AT 17
94.8
96.2
95.0
96.8
98. 1
98.7
98.7
96.8
99.4
99.4
92.9
92.2
92.3
92.3
87.2
97.5
96.3
90.4
91 .3
94.5
97.6
89.9
86.5
86. 1
88.4
84>6
82.9
89.2
R5.2
92.9
94. 1
85.9
89.7
.34
• 35
• 34
• 38
.29
• 29
.27
.29
.27
.27
.26
.20
.19
• 20
.20
• 18
. 18
.18
. 17
• 16
.16
• 12
.23
• 03
.29
.30
.29
.29
.29
.29
.29
.29
• 29
•2030 FOR
67.
67.
74.
67.
74.
69.
76.
76.
74.
69.
74.
74.
69.
74.
76.
69.
76.
69.
69.
77.
76.
76.
77.
71 .
72.
69.
74.
68.
74.
73.
76.
77.
73.
72
22.2
20.9
20.1
20.6
20.9
22.2
21.0
19.8
20.1
20*1
20.2
19.5
19.1
19.8
19.5
19.1
19.0
19.2
19.2
19.0
18.9
19.0
18.9
19.0
18.4
18.9
18.4
19.2
19.5
19.2
19.7
19.5
19.1
HOURS
2.69
.52
.70
.70
.61
.59
.57
• 15
• 33
• 33
• 17
.26
1 .23
1.08
.20
.26
.28
.42
.34
.44
.41
.44
.43
.53
.05
0.73
0.94
1 .26
1 .53
1 .44
0.99
1.17
0.93
26.0
16.5
32.6
37.0
33.9
36.3
26.4
28.5
37.2
45.7
36«8
30.9
45.0
36.8
33-7
39.3
48. 1
38.5
43.8
33.2
65.2
43.2
57.4
60.0
38.9
35.6
36.5
36.5
36.5
41 .6
34.3
51.9
43.6
27.6
17.9
33.7
38.2
37.3
38.8
26.6
29.7
37.0
44.5
36.4
29.4
39.6
36.7
3L8
37.0
39.9
38.5
39.5
31.5
47.1
36.1
46.0
48-5
38.2
36.6
35.0
38.0
34.0
43.5
36.5
46. 1
39.8
- 195 -
-------
RUN 5:
APPENDIX
DESULPHURISATION
Bt TABLE IV.
PERFORMANCE PAGE 7 OF 9
DAY. HOUR
22.0530
22.0630
22.0730
22.0830
22.0930
22.1030
22.1130
22-1230
22. 1330
22.1430
22.1530
22. 1630
22.1730
22. 1830
SULPHUR GAS
REMOVAL VEL.
X M/S
89.6
90.7
90. 1
92. 1
90.1
88.4
87.1
86.8
78.2
78.3
79.6
86.5
84.2
83-9
.29
.27
• 27
• 30
.29
.29
.29
• 30
.29
.30
.29
.30
.30
.28
G-BED
DEPTH
CENTIM
73.
73.
77.
73-
73.
77.
74.
74.
76.
76.
76.
76.
76.
76-
AIR/
FUEL
X ST.
19.0
19.5
20*0
19.1
19.5
19.5
19.5
19.6
19.0
19.7
19.8
19.7
19.7
19-7
CAO/S REGEN.
RATIO % CAS S OUT X
MOL. TO CAO
0.93
1.03
1.04
1*11
1*14
1.02
0.92
1.02
1 .06
0.93
0.96
1.15
0.95
1*12
42.6
47.0
36.3
54.2
33.4
26.7
35.2
46.8
50.5
47.3
44. 1
33.5
45.6
29.9
OF FED
44.6
49.7
37.8
49.5
36.3
27.8
36.9
36.7
50.7
45.5
45.3
33.4
45-8
29.0
SHUT DOWN AT 22.1830 FOR 23 HOURS
23.1730
23.1830
23. 1930
23.2030
23.2130
23.2230
23.2330
24.0030
24.0130
24.0230
24.0330
24.0430
24.0530
24.0630
24.0730
24.0830
24.0930
24.1030
24. 1 130
24. 1230
24. 1330
24. 1430
77.3
88.7
91.3
-
91.3
91.4
91.2
99.1
99. 1
99.3
98.9
98«9
99.3
99.3
99.3
99.3
99.3
99.3
99.3
99.3
99.3
96.1
.35
.36
.36
• 39
.28
.33
.34
.38
• 39
• 35
-35
.35
• 33
• 34
.28
.28
.32
• 32
• 31
• 29
• 35
• 31
67.
72.
76.
78.
79.
83.
83.
79.
83.
93.
87.
87.
87.
87.
87.
87.
88.
92.
86.
90.
86*
84.
17.7
18.2
18.6
19.6
17.6
18.5
18.7
19.9
19.6
19.4
19.3
19.1
19.4
19.5
18*1
19.4
19.8
20.8
19.7
18.7
19.2
18*9
2.36
2.36
2.41
2.22
2.20
2*31
2.31
2.30
2.27
2-29
2.11
2*04
2.13
2.01
2.03
2*48
2.48
2.20
2.31
1.92
0.67
0.96
15.2
27.8
37.7
10.8
24. 4
31 .4
12.6
39.5
31.9
37.2
38.5
35. 1
32.0
32.6
47.5
43. 1
26.3
26.6
39.0
36.2
43.7
38.9
1 7.6
31.2
44. 1
12.3
26.4
34.4
14.0
45.2
36.1
41*2
40.4
37. 1
32-1
35>6
49.3
44.5
28.3
28.7
42.5
38.0
46.4
42.7
- 196 -
-------
RUN 5:
APPENDIX B: TABLE IV.
DESULPHURISATION PERFORMANCE PAGE
8 OF 9
DAY. HOUR
24-1530
24. 1630
24.1730
24. 1830
24. 1930
24.2030
24.2130
24.2230
24-2330
25.0030
25.0130
25.0230
25-0330
25.0430
25.0530
25.0630
25.0730
25.0830
25.0930
25. 1030
25. 1 130
25*1230
25.1330
25. 1430
25. 1 530
25. 1630
25. 1730
25. 1830
25. 1930
25.2030
25.2130
25.2230
25.2330
26.0030
26.0130
26.0230
26.0330
26.0430
26.0530
26.0630
SULPHUR GAS
REMOVAL VEL.
% M/S
96.1 1.31
97.4 1.34
91.6 1.36
-
-
-
-
-
96.0
91 .5
94.2
89.3
92.8
94.7
95.4
92.7
94.3
90.3
95.4
-
98.6
85.7
92.9
89.9
89.9
87.3
• 31
.33
.34
• 32
• 32
.32
.31
.32
.31
• 32
.32
.32
.32
.32
• 32
.28
.32
.26
.26
.32
.32
• 31
.32
90.3 1.31
90.0 1.35
86.4 .31
88.4 .31
89.6 .32
91.4 .32
90.3 .27
90.8 .26
92.9 .31
91.3 .28
90.0 .28
88.5 .29
91.0 .29
89.1 .29
G-BED
DEPTH
CENTIM
82.
82.
87.
90.
90.
90.
90.
94.
90.
90.
90.
90.
92.
92.
90.
90.
90.
90.
92.
87.
87.
88.
92.
92.
92-
110.
94.
92.
97.
97.
95.
94.
94.
90.
90.
90-
90.
90.
90.
90.
AIR/ CAO/S
FUEL RATIO
% ST. MOL.
18.7
18.7
19.7
18.6
18.6
18.7
18.8
19.0
19.1
18.9
18.9
18.9
19.0
19.2
19.1
19.1
19.4
19.2
18.2
19.2
18*4
18.2
19.1
19.2
19.2
19.3
18.6
19.0
18 * 7
18.7
19.1
19.2
18.0
17.9
18.8
18.3
19.2
.21
• 28
.51
.47
.67
.54
.51
.67
.45
.67
.74
.61
.67
• 30
.45
.58
• 37
.59
.46
.58
.27
.52
.46
.35
.20
.40
.95
.05
.02
• 15
• 98
.15
.15
.15
.02
. 1 1
.02
18.7 1.08
18.8 1*02
18*8 0*86
% CAS
TO CAO
39.3
35-8
35.5
38.9
35.4
30.6
26.8
37. 6
23-3
23.0
17.6
26.3
38.4
36.0
35.9
36.7
38.6
31 .8
30.5
34.4
41 .4
37.8
47. 1
29.9
28.2
33.5
37.6
38. 1
38.2
35-6
40.3
33.3
32.2
44. 3
36.2
25. 1
30.2
30.6
40.7
43. 1
REGEN.
S OUT %
OF FED
42.2
38.9
38.3
41 .9
38.2
35.0
30.5
43.6
26.7
28.5
20.0
30.6
43.8
42.0
41 .9
43.8
44. 7
37.8
35.7
40. 1
48.5
43.4
51.7
30.3
31»3
37.8
42. 9
43.2
41 .9
38. 0
41.9
35-8
33.6
46*0
38.5
28.4
35.4
35.4
44.5
48.2
- 197 -
-------
RUN 5:
APPENDIX
DESULPHURISATION
B: TABLE IV.
PERFORMANCE PAGE 9 OF 9
DAY. HOUR
26*0730
26.0830
26.0930
26*1030
26.1130
26.1230
26*1330
26*1430
26.1530
26* 1630
26.1730
26.1830
SULPHUR GAS
REMOVAL VEL.
% M/S
89.9
92.4
90.3
90.3
92.9
90.3
90.3
92.3
88*4
85.9
86.0
83.9
.30
• 27
.29
.23
.23
• 24
.25
• 37
• 27
.28
.25
• 25
G-BED
DEPTH
CENTIM
90.
90.
90.
97.
95.
97.
95.
97.
99.
99.
99.
97.
AIR/ CAO/S
FUEL RATIO
Z ST. MOL.
18.7
18.2
18.8
17.4
17.5
17.8
17.8
20.5
18-7
18.7
18.3
18*8
• 37
.40
.21
• 36
.40
• 43
.34
.43
.66
.37
• 34
.38
I CAS
TO CAO
20.0
32.3
33.1
38.3
34.4
46.9
35.2
31 .6
33.7
32.1
35.3
35. 1
RE GEN.
S OUT %
OF FED
22-3
35-9
37.4
43.9
36.7
49. 1
40.2
35.6
37.3
35.0
36.9
38.8
- 198 -
-------
- 199 -
-------
APPENDIX B - Table V
RUN 5: GAS COMPOSITIONS
to
O
O
DAY.HOUR
2
2
2
2
2
2.
2.
2.
2.
2.
0230
0330
0430
0530
0630
0730
0830
0930
1030
2.1130
2.1230
2.1330
2.1430
2.1530
2.1630
2.1730
2.1830
2.1930
2.2030
2.2130
2.2230
2.2330
3.0030
3-0130
3.0230
3.0330
3-0430
*• F L U E GAS
REGEN&RATOR GAS
02
COP
VOL *
% ANAL
2.
3.
3-
2.
2.
3.
2.
2.
3.
0.
1 .
3.
2.
2.
2.
2.
2.
2.
2.
2.
2.
2.
2.
2.
2.
2.
8
0
3
7
8
5
5
1
0
8
5
0
8
0
1
4
0
0
5
0
3
4
0
6
6
3
4.
4.
3.
3.
3.
2.
3.
4*
4*
5.
5.
4.
5.
4.
4.
4.
4.
4.
4.
4.
4.
4.
4.
4.
4.
4.
4
4
2
8
5
7
5
4
4
6
3
4
0
7
4
4
7
7
1
7
4
4
4
4
1
4
CALC
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
3.6
3.4
3.P»
3.5
3.4
2.9
3-9
MI
4. 1
3.5
5.0
4.5
3.4
3*6
4.2
4. 1
3.9
4.2
4.2
3-9
4.2
4. 1
3-9
4.2
MI
3.8
3.8
4*0
SO?
PPM
210
228
328
255
55
27
429
SSED
757
748
547
520
565
492
474
420
347
365
337
337
338
420
420
420
SSED
419
401
401
02 C02
•
•
*
•
•
•
•
0.
0.
0.
0.
0.
0.
0.
DATA
•
•
•
•
*
•
*
•
•
•
•
•
•
•
•
•
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
DATA
•
•
•
0.
0.
0.
*
0
0
0
0
0
0
0
READI
0
0
1
40 0
0
1
1
1
1
0
0
0
READ
*
.5
.6
.6
.5
.9
.5
,7
NG
.6
.6
.7
• 8
.6
• 3
.3
. 1
.0
.8
.8
.6
.5
.7
.0
.2
NG
.0
.3
.9
S02
%
2.9
3.9
5.4
4.2
5.4
4.6
3.9
2.7
3-9
2.9
1 .8
4.4
5.8
5.0
5.0
4.6
5.8
5-8
2.2
4.0
5.0
5.0
4.0
6.0
4.6
4. 4
PAGE I OF 6
GASIF-IER INLFT GAS
02 VOL I C02 VOL X
ANAL CALC ANAL CALC
16.5
16.5
15-0
15.0
15.0
15.0
15.0
15.5
16.0
14.0
14.0
14.5
14.0
14.5
14.5
14.5
14.8
14-8
15.0
14.0
14.5
15.0
15.0
15.0
15. 0
15.5
7.3
7.4
6.4
6.6
6.7
7.0
6.9
7.3
6.3
3.3
5.0
6.0
5.7
6.3
6.4
6.5
6* 1
6. 1
7. 1
7.0
9.4
7.1
6.9
2.68 2.89
2-60 2.89
3-36 3.46
3.27 3.29
3.18 3.23
3.10 2.91
3-01 2.97
2.76
2*44
3-63
3.54
3.27
3-45
3-27
3. 10
3.10
2.93
2.93
2.76
3.27
3.01
2.84
2.76
2.84
3.75
5.96
4.67
4.01
4.33
3.59
3.52
3*44
3.79
3.79
2.93
3- 1 1
1 . 19
3.03
3. 1 1
7.1 2.68 3-02
7.4 f>.60 2.77
7.? 2.60 2.89
-------
3.0530
3.0630
3.0730
3.0830
3-0930
3.1030
3 • 1 1 30
3.1230
3. 1330
3.1430
3.1530
3.1630
3.1730
3. 1830
3. 1930
3.2030
3.2130
3.2230
3.2330
4*0030
2.3
2. 1
2. 1
2.0
2.0
1 .8
1 *8
2.0
2.0
2.5
1 .5
2.0
2.0
2.8
2-8
2.2
2.1
1 .7
4. 1
4.7
4.4
4.7
4.4
4.4
4.4
4.4
4.7
3-8
4.4
4.4
4*4
3.5
3-5
4.4
4.7
4*4
2«1 0.0
2.1 0.0
14.0
14.2
14.2
14.2
14.2
14.4
14.4
14.2
14.2
13.8
14.6
14.2
14.2
13.6
13.6
14. 1
14.2
14.5
14.3
14.3
410.
383.
401 .
319.
292.
392.
347.
356.
319.
438.
401 •
365.
474.
474.
565.
620.
602.
584.
684.
803-
0.
0.
0.
0.
0.
0.
0.
0.
1 .
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
05 .0
05 • 1
• 4
.3
. 7
• 1
0.8
0.8
00 0.8
1 .7
0.8
0.4
1 .0
1 *6
1.6
0.8
0.6
1 .6
0.2
0*0
3.9
3.9
4.4
4.4
4.6
4.0
2.2
3.5
1 .0
5-0
3.5
4.2
3.9
4.4
4.4
1 .2
1.2
4.6
1 .5
4.2
15.5
15.5
15.5
16.0
16.0
15.5
15-0
15.0
1 4.5
14.5
15-5
15.5
15-2
15-5
15.5
15.5
15.2
15-2
15. 1
15.2
17.4
17.2
17.2
17.2
17.0
16.3
16.1
16.2
16.0
15-8
15.6
15.4
15.7
16.2
16.5
15.9
16.7
17.2
17.0
17.0
2.52
2.52
2.52
2.52
2.44
2.76
2.76
2.93
2.93
3. 10
3. 10
2.93
3.01
3.01
3.01
2.93
2.93
2.76
2.93
2.93
2.71
2.96
2.90
2.96
3.00
3-55
3.69
3.60
3.89
3.85
4.01
4.20
4.00
3.57
3-33
3-86
3.30
2.79
0 .00
0.00
1 STONE CHANGE
£ 4.0130
M 4.0230
, 4.0330
4.0430
4.0530
4.0630
4.0730
4.0830
4.0930
4. 1030
4. 1 1 30
4.1230
4. 1330
4. 1 430
4. 1530
2.3 14.4
2.6 14.4
2.6 14.1
2.3 14.4
2.5 13.8
3-0 14.4
3.0 14. 1
4.0 13.0
3.5 13.5
3. PI 14.4
2.5 13.8
3.0 13.8
3.5 13.2
2.5 13-8
14. 1
13.8
13.8
14.0
13.8
13.4
13.5
12.7
13.1
1 3.5
13.9
13.5
MI
13. 1
13.8
420.
420.
401 .
401 .
137.
374.
237.
492.
-
319.
-
520.
0.
0.
0.
0.
4*
0.
0.
0.
0.
0.
0.
2.
SSED DATA
59.
347.
0.
0.
• 1
.0
.3
.9
50 «0
.6
1 .8
1 • 1
0.2
1 .3
0.4
00 0.3
READING
1 .3
0.4
5.0
6.0
4.6
4.4
-
2.9
5.8
5.4
4.6
5.8
6*6
3.5
6.2
5.0
1 5.0
15.0
15.0
15.0
16.0
16.0
16.0
16.5
16-5
15.5
1 4.0
16.0
15. P)
1 5.0
17.4
17.5
17.6
17.6
14.9
16.3
17.5
17.3
17.2
16.8
16.3
16.4
16.8
16.7
2.76
2.68
2.60
2.60
3. 10
2.84
2.76
2.60
2.44
2.93
3.63
3.01
3. 10
2.93
2.73
2.73
2.62
2.59
4.58
3.73
2.77
2.82
2.93
3-38
3-52
3.51
3.21
3.21
-------
RUN 5:
GAS COMPOSITIONS
PAGE 2 OF 6
to
O
10
DAY.HOUR
4-1630
4-1730
4*1830
4.1930
4.2030
4.2130
4.2230
4.2330
5.0030
5.0130
5*0230
5.0330
5.0430
5.0530
5.0630
5-0730
5*0830
5-0930
5.1030
5 • 11 30
5.
5.
5.
5-
5-
1230
1330
1430
1530
1630
6
6
0230
0330
F L
02
Z
4.0
4-0
3-0
2.8
3.5
3.2
3-5
4.5
3.5
3*0
3.0
3*0
3.0
3.0
3.5
3.0
3*0
3.0
2.5
2.5
2.0
2.2
2.5
U E GAS
C02 VOL Z
ANAL
13.2
12.7
13-2
13*8
13.8
13.8
14. 1
13-0
13*0
14.4
14.4
14*4
14.4
13.8
13.2
14.4
14*1
14.4
14.4
14.7
14.4
14.7
14. 1
CALC
12.7
12-7
13-5
13-6
13-1
13.3
13. 1
12-3
13.1
MI
13.4
13.4
13-5
13.5
13-5
13. 1
13*4
13-4
13.4
13.8
13-8
MI
14.2
14.]
13.8
SO?
PPM
356.
237.
82.
137.
-
-
-
164.
155.
REGENERATOR GAS
02 C02
0
0
0
0
0
0
0
0
0
SSED DATA
128.
18*
137.
164.
91 .
46.
73.
91 •
91 .
82.
128.
0
0
0
0
0
0
0
0
0
0
0
SSED DATA
164.
100.
73.
0
0
0
Z
0
• W
1
1
* w
I
1
0
0
READI
1
0
0
0
1
0
1
2
1
2
0
READI
1
0
0
Z
.2
.2
.2
.4
• 6
• 1
.0
• 5
• 6
NG
.0
.6
• 6
.4
.0
• 6
.6
.0
.7
• 1
.8
NG
-3
.4
.7
S02
Z
4.2
3. 1
6.?
5.8
5-8
6.6
6.2
5-6
6.6
1 .8
1.2
5.0
4.2
5.4
5.0
5.4
6-2
5.8
6*0
5.8
6.?
6.2
5.6
GASIFIEP
02 VOL Z
ANAL
15-8
15.5
15.5
15.5
15.8
15.5
16*0
15.0
17.0
16.0
16.0
16.0
16.0
16.0
16.0
16.0
16*0
16.0
16.5
16.5
16.5
17.0
1 7.0
CALC
16.9
17.1
16.9
16.8
16.9
17.5
17.4
15.3
16.5
16.7
16.9
16.7
17.5
17.1
17.0
16.9
16.9
16.9
17.2
16.9
16.9
17.1
17.2
INLET
GAS
CO? VOL Z
ANAL
2.84
2.76
2.93
3.01
2.76
2.93
2.8^
3.27
2.44
2.76
2.93
2.76
2.84
2.76
2.76
2.76
2.93
2.93
2-60
2.76
?.60
2.60
?.60
CALC
3.15
?-91
3.03
3- 16
3.23
2.72
2.8P
4.52
3.36
3.40
3.23
3*40
2.81
2.98
3-02
3.28
3-21
3-27
2.92
3.24
3» 1 1
3-06
2-9CI
SHUT DOWN AT 5.1630 FOR 10 HOURS
2.
1 -
5
5
14.
15.
13.8
14.5
338.
246.
0.
0.
1 .7
2.5
4.2
4.6
15.0
15-0
16.
16-
8
2
3.
3-
36
45
30
67
-------
8*
8.
9.
9.
9.
9.
9.
9.
2230
2330
0030
0130
0230
0330
0430
0530
1
12
12
• 1430
• 1530
• 1630
• 1730
.1830
.1930
• 2030
• 2130
.2230
.2330
0030
0130
1 .
3.
2.
1 •
2.
SHUT
3.
3.
2-
3.
2.
3-
3.
2.
SHUT
3.
3.
4.
3.
3.
3.
4*
4.
4.
3-
4.
5
0
0
5
0
15
14
15
15
15
.0
.4
• 0
.6
.0
DOWN AT
0
0
5
2
7
0
0
2
13
14
14
14
14
14
14
14
.8
.1
• 4
. 1
• 1
• 1
.4
• 4
DOWN AT
5
5
0
8
5
5
0
0
0
5
0
13
13
13
13
13
13
13
13
13
13
13
.5
• 8
• 5
• 8
.2
.2
.2
• 2
.5
• 5
.8
4
3
4
4
4
6
13
13
13
13
13
13
13
14
9
13
13
12
12
13
13
12
12
12
13
12
•
•
•
•
•
5
4
2
6
2
173.
91.
27.
55.
27.
.0830 FOR
•
•
•
•
•
*
*
•
4
4
8
3
6
4
4
0
356.
356.
328.
310.
164.
119.
173.
274.
.0530 FOR
•
*
*
*
•
*
•
•
•
•
•
0
1
7
9
1
1
7
8
7
1
7
MI
356.
237.
228.
228.
91.
55.
109.
255.
210.
337.
365.
0.
0.
0.
0.
0.
1
2
1
2
3
.7
.0
.7
• 2
.1
3.5
5.0
6.2
5*6
6.6
62 HOURS
0.
0.
0.
0.
0.
0.
0.
0.
5
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
SSED DATA
20 0
20 0
0
0
0
0
1
0
• 8
.5
.4
.8
.6
.9
.0
.9
-
0.7
-
1 .8
1 .8
-
3*1
3-9
7 HOURS
0
1
1
0
0
0
1
1
0
1
1
READI
.8
.0
.0
.6
.7
.6
.0
.0
• 8
.0
• 5
NG
2.7
1.2
3.5
2-2
4.6
3.5
5.0
3.9
5.0
5.4
6.2
15.
16.
16.
16.
16.
5.
5.
5.
5.
5.
6.
6.
6.
6.
6.
6.
6*
6*
7.
7.
6.
6.
6.
6.
5
0
0
0
Pi
7
7
3
8
8
0
0
0
0
0
5
0
5
0
0
5
5
5
8
1
1
1
1
1
1
1
1
1
1
1
I
1
1
1
1
1
1
1
1
1
1
1
1
6
7
6
7
6
6
6
6
6
6
6
6
6
6
7
7
7
6
7
7
8
7
7
7
•
•
»
•
•
*
•
•
•
•
*
*
•
*
»
•
*
*
*
*
*
•
*
•
0
0
9
1
6
1
0
2
3
4
7
7
7
7
2
3
3
7
6
8
6
8
2
7
3
2
3
2
2
4
3
4
3
3
3
3
3
4
4
4
4
3
3
3
3
4
3
2
• 45
.93
.10
.93
• 93
• 02
• 82
.02
.63
• 63
.45
.45
• 45
• 42
.02
.02
.02
.82
.63
• 45
.27
.02
.92
.76
3-
3-
3.
3.
3.
3-
3.
3-
3.
3-
3.
3.
3.
3.
3.
2.
3»
3-
2.
2.
1 •
2.
2.
2.
81
17
25
1 1
49
77
92
71
68
55
40
47
31
34
01
94
00
23
60
46
84
51
92
64
-------
RUN 5:
GAS COMPOSITIONS
PAGE 3 OF 6
DAY.HOUR
to
O
12-
12-
12.
12
12
12
0330
0430
0530
0630
0730
0830
12.0930
12.1030
12.1 130
12.1230
12.1330
12.1430
12.1530
12.1630
12-1730
1830
• 1930
2030
12.
12.
12.
12.
12.
12.
13.
13.
13.
!3«
13.
13.
2230
2330
0030
0130
0230
0330
0430
0530
0630
F L
02
Z
4.0
3.5
3.5
3.0
4.0
4*0
4.2
3.7
3.5
4.0
3-5
3.3
3.6
3-3
3.7
3.8
4.0
3.0
3.7
3.2
4.6
3.4
4. 1
3.7
4.2
3-9
3-9
U E GAS
C02 VOL Z
ANAL
13-2
14.1
14.1
14.1
13.2
13*2
13.5
13.8
13.8
13.8
13.8
14.1
13-8
13.8
14. 1
13.8
13.2
13.8
13.5
14.1
14. 1
14* 1
13.2
13.5
13.2
13-2
13.5
CALC
12.9
13-1
13.1
13-5
12-7
12.7
12-3
13*0
MI
13.1
12.7
13. 1
13.2
13-0
13.3
13.0
12.9
12.7
13.5
12.9
13.3
12-2
13.1
12.6
13.0
12.6
12.8
12.8
S02
PPM
274
255
246
392
292
274
237
237
SSED
255
210
210
228
219
219
201
210
228
274
310
301
237
265
201
P65
164
137
164
•
•
*
•
•
•
•
•
REGENERATOR GAS
02 C02
Z Z
0. 0.8
0.
0.
0.
0.
0. f
0.
0.
DATA READ
•
•
*
•
•
•
•
•
•
•
•
•
•
•
•
•
*
•
•
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0. J
0.
0.
0.
0.
0.
0.
• 3
. 1
• 3
.2
5.8
.1
.3
NG
.6
.3
.4
.6
.9
.9
.3
• 3
• 3
.9
.0
.9
>«0
• 6
.4
.6
.4
.4
.5
S02
Z
5.4
5.4
3.7
4.6
4.6
4.6
4.0
3.9
3.1
4.4
3.5
4.8
3.5
5.0
4.6
4.6
4.6
3.9
4.6
4.0
4.2
4.0
4.8
4.0
4.2
4.6
3.9
GASIFIER
02 VOL Z
ANAL
16.5
16.5
16.5
16.0
16.0
16.0
16.7
17.0
17.0
17.0
17.0
17.0
17.0
17.0
17.2
17.0
17.0
16.7
16.7
15.7
15.7
15.8
16.0
1 5.8
16.0
16.?
15.9
CALC
17.6
17.5
17-5
16-9
16.4
16.4
17.2
17-6
17.6
17.7
17.6
17.4
18.0
17.9
18.3
18.3
18.2
17.2
16.9
15.8
16.3
15.9
16. 1
16.4
16.6
16. 1
16.0
INLET
GAS
C02 VOL Z
ANAL
2.60
2.84
2.76
2.93
3.10
3.01
2.76
2.60
2.60
2.44
2.44
2.44
2*44
2.44
2.44
2*44
2.44
2.68
2.68
3. 18
3. 18
3. 10
3.01
3 • 1 0
?.93
2.93
3.01
CALC
2.62
2.79
2.79
3- 18
3-57
3.57
3.09
2.71
2.70
2.70
2.71
2.90
2.34
2.42
2.22
2.17
2.21
2.9?
3. 1 7
4*08
4.07
4.PI7
3.83
3.56
3.49
3.83
3.91
-------
SHUT DOWN AT 13.0630 FOR 73 HOURS
l/l
16*0730
16*0830
16*0930
16*1030
16* 1 130
16*1230
16*1330
16*1430
16.1530
16*1630
16-1730
16. 1830
16. 1930
16*2030
16*2130
16*2230
16*2330
17.0030
17.0130
17.0230
17.0330
17.0430
17.0530
17.0630
17.0730
17.0830
17.0930
17. 030
17. 1 30
17. 230
17. 330
17. 430
4.0
4.0
3.0
3.0
3.0
3.5
3.0
4.0
4.0
3.0
3.0
3.0
3.0
3*0
2.5
3.0
3.0
-
-
-
-
-
-
-
3*0
3.0
3.0
3*0
2.8
2.7
13.8 12.8 456. 0. 0.6 - 21.0 21.0 0.02 0.
14.4 12-8 474. 0. 1.0 1.2 20.5 20.5 0.34 0.42
14*4 13.4 447. 0. 1.0 - 6.0 16.9 3-27 3-30
14*4 13.4 374. 0. 1.0 4-2 5.5 16.8 3.45 3-39
14.4 13.4 347. 0. 0.8 3-5 5-8 16.9 3.45 3.30
14.4 13.1 429. 0. 0.4 3.5 6.0 16. R 3.10 3.47
14.1 13.4 365. 0* 0*8 5.0 6-5 16.5 3-27 3-54
MISSED DATA READING
13.5 12.7 328. 0« 0.6 3-5 16.8 16.9 2.84 3-25
13.5 12.7 337. 0. 0.6 4.6 6-5 17.2 2.76 3.05
14*4 13*4 346. 0* 0*6 5*6 6*8 17.0 2*68 3*18
14.4 13.4 310* 0> *0 5.6 7.0 16*8 2.76 3*34
14.4 13*4 64. 0* .0 4*6 7.0 16*9 2*60 3*28
13*8 13.4 27. 0. 0.8 5-8 7.0 16-8 2-76 3-21
14.4 13»4 18. 0. .9 1.5 7.0 16.9 2.60 3.28
14.4 13*8 18. 0* >7 4.2 7.0 16*9 2.60 3.20
13*8 13.5 18. 0- .6 3-5 7.0 17.0 2-60 3*07
13.8 13*5 27. 0. .1 3.9 7.0 17.1 2.60 3.01
8.3 - 0. •! 5.0 7.0 18.6 2.44 0.36
8.3 - 0. «0 4.6 7.0 18.5 2. 44 0.05
8»3 - 17.50 0.0 -0.0 7.0 18.5 2*44 0.44
8*3 - 0* *1 4.6 7.0 18.5 2.44 0.51
8.3 - 0- «4 4.6 7.0 18.3 2.44 0.39
8.3 - 0- .6 4*2 7.0 18.5 2.44 0.24
8.3 - 0. •! 4*6 7.0 18.5 2.28-0.67
MISSED DATA READ NG
3.8 3.5 164. 0. .7 4.6 7.0 17.0 2.44 3.08
4«1 3*4 228. 0. .9 4.6 7.0 17.0 2.44 3. 14
4.1 3.5 283. 0. .6 5.6 7.0 16. R 2.44 3-26
4.1 3.5 274. 0. .7 5.4 7.5 17.4 2.20 P. 80
4.4 3.6 ?37. 0. .6 5-0 7.0 17.3 2.44 2-91
14.1 3.7 410. 0. 2-6 5.0 7.2 17.3 2.44 2-87
-------
RUN 5:
GAS COMPOSITIONS
PAGE 4 OF
DAY-HOUR
17.
17.
17.
17.
17.
17.
1530
1630
1730
1830
1930
2030
FLUE GAS
02 C02 VOL X
Z ANAL
3*0
2.8
2-8
2.8
2.5
2.7
4. 1
4.4
4.4
4.4
4.4
4.4
CALC
13.4
13.6
13.6
13.8
13.8
13.7
S02
PPM
383.
201 .
392.
274.
228.
128.
REGENERATOR GAS
02 C02 S02
Z
0.
0.
0.
0.
0.
0.
%
1 •
0.
1 .
3.
1 •
3.
6
4
6
I
6
1
Z
4.6
2.7
4.0
5.4
4.6
4.6
GASIFIER
OP VOL Z
ANAL
17.0
17.0
17.5
17.5
17.5
17.7
CALC
17.3
17.2
17.5
17.4
17.1
17.3
INLET GAS
C02 VOL Z
ANAL
2.20
2.44
2.28
2.12
1 .96
2. 12
CALC
2.87
3.04
2.75
2.81
3-02
2.87
STONE CHANGE
SHUT DOWN AT 17.2030 FOR 72 HOURS
to
O
o\
1
20.2030
20.2130
20.2230
20.2330
21 .0030
21 .0130
21 .0230
21 .0330
21 .0430
21 .0530
21 .0630
21 .0730
21.0830
21*0930
21.1030
21.1130
21.1230
21*1330
21-1430
21 .1530
2.0
1 .6
1 .4
2.0
2.0
2*0
2.0
1 .8
1 .8
2.0
2.2
2.3
2.2
2.0
2.0
1 .5
1 .2
2.0
1 .5
1 .2
15-0
15*6
15.6
15.3
15.0
15.0
15.0
15.0
15.3
15.3
15.3
15.0
15.0
15.0
14.7
15.3
15.3
14.4
15.3
1 5.3
4.2 73« 0.20 1.3 2.7 18.0 18.4 1.65 2.04
4.5 55. 0.20 1.3 1.8 17.5 17.8 2.20 2.53
4.7 73. 0.20 2.8 3-5 17.7 17.9 2.12 2.47
4*2 46. 0.20 2*6 4*0 18.0 18*1 .81 2*33
4.3 27. 0.20 1.1 4.0 19.0 19.0 .33 1*57
4-3 18. 0-20 1.5 4.2 19.0 19.0 .24 1.57
4.3 18. 0.40 1.3 3-1 19. 3 19. 3 .08 .34
4*4 46. 0.20 0.8 3*5 18.7 18.7 .41 .79
4.4 9. 0.20 1.9 4.2 18.8 18.8 .33 .75
4.3 9. 0.20 2-6 5.0 18.8 18.8 .33 .77
4.1 100. 0.20 1.8 4.2 19. PI 19.0 .33 .62
4.1 109. 0.30 2.0 3.5 19.0 19.0 .33 .60
4.1 109. 0.20 3-7 4.6 19.0 19. P> -33 -59
4-3 109. 0.20 1.9 4.2 19-0 19.0 .33 .57
4.3 182. 0.20 1.9 3.9 19. P) 19.0 .24 .54
4.7 37. 0.10 2.3 4.4 19. P) 1 9 . P» .33 .56
4.9 55. 0.10 4.7 4.6 19. PI 1 9 . PJ .33 1.54
4.3 137. 0.1PI 1.3 4.6 19. P) 19. P) .24 1.51
4-6 128. 0.10 3-3 4.6 19. P> 1 9 . P! .?4 1.56
4.9 82. 0.10 1.7 3-9 19.0 1 9 . P) .24 1.54
-------
21.1630
21.1730
21.1830
21 .1930
21.2030
21 .2130
21.2230
21.2330
22.0030
22.0130
22.0230
22.0330
22.0430
22.0530
22.0630
22.0730
22.0830
22.0930
22.1030
22-1130
22.1230
22.1330
22.1430
22.1530
22.1630
22.1730
22.1830
23.1730
23.1830
1.0 15.0 15.0 37.
1.8 14.7 14.4 146.
1.2 15.3 14.8 201.
1.8 15.3 14.4 201.
2.0 14.7 14.2 164.
2.0 14.7 14.2 219.
1.7 15-0 14.4 246.
1.7 15.0 14.4 155-
2.0 15.0 14.2 210.
2.1 15.0 14.1 100.
2.2 14.7 14.1 82-
2.0 15.1 14-2 201.
2.1 15.0 14.1 146.
2.2 15.0 14.1 146.
2.6 15.0 13.7 128.
2.5 14.7 13.8 137.
2.5 14.7 13.8 109.
2.5 14.7 13*8 137.
2.0 15-0 14.2 164-
2.0 15.0 14.2 182.
2.5 14.4 13.8 182.
2.0 14.4 14.2 310.
2.5 14.7 13.8 301.
2.5 14.7 13«8 283.
2.0 14.7 14.2 192.
2.5 14.4 13-8 219.
2.0 14.5 14.2 228.
0.10 6.7 5.4
0.10 4.3 4.2
0.10 4.6 5*6
0.10 4.9 5.B
0.10 2.8 4.2
0.20 3.5 3.7
0.20 4.5 3.5
0.20 3-1 3.9
0. 4.5 3.5
0.50 2.6 4.4
0.30 2.6 3.9
0.30 5.7 4.6
0.20 4.5 3.9
0.20 2.6 4.6
0.20 3-1 5.0
0.20 2.9 3.9
0. 5-2 5.0
0*10 1*6 3*9
0.10 1.7 3*1
0. 2-6 3.9
0. 5.2 4.2
0*10 3*1 5*4
0.10 4*3 4.6
0.10 3.3 4.6
0.10 3.3 3-5
0.10 3.8 4.6
0.10 3.3 3.1
SHUT DOWN AT 22*1830 FOR 23 HOURS
19.
19.
18.
20.
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
7.
5.
5.
6.
6.
6.
6.
6.
6.
6.
6.
7.
6.
6.
6.
6.
6.
6.
6.
6.
6.
6.
6.
.0
5
.0
5
0
8
7
4
5
7
8
8
8
8
9
0
5
5
5
5
5
5
5
5
5
5
5
19
19
17
20
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
6
6
5
6
6
6
6
6
6
6
6
7
6
6
6
6
6
6
6.
6-
6.
6.
6.
.0
.5
.9
.5
.9
.0
.9
.6
.7
.7
.7
.7
.7
.7
.7
.0
.7
.9
• S
.8
.9
.8
.9
.8
.8
.8
,7
1.24
1 • 16
1 .81
0.
2.
3-
3.
2-
2-
2.
2.
2.
2.
2.
2.
2.
1.
2.
2.
2.
2.
2.
2.
2.
2.
2.
2.
23
.60
27
27
93
93
84
76
76
76
76
68
60
81
76
76
76
60
68
68
60
60
60
60
1
1
2
0
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3
3.
3.
3.
3.
.50
• 14
.39
. 40
• 19
• 85
.92
.43
• 41
• 41
.34
.45
• 41
.41
.48
• 17
.41
• 26
• 32
-32
. 19
. 19
.26
.30
.26
.23
• 31
2-
2.
0
5
14.
14.
14. 1
13.8
319
155.
0.30
0.2PI
1 .0
2.0
1 .
3.
16.
16.
15.6
15.9
3.
3.
10
10
.?(*
-------
RUN 5:
GAS COMPOSITIONS
PAGE 5 OF 6
O
oo
DAY. HOUR
23-1930
23.2130
23.2230
23.2330
>0030
0130
.0230
.0330
24.
24.i
24.i
24.i
24.
24.
24.
24*
24.
24.
0430
0530
0630
0730
0830
0930
24.1030
24.1130
24.1230
24*1330
24.1430
1530
1630
1730
1830
1930
2030
24.2130
24.2230
24.
24.
24.
24.
24.
24.
F L
02
*
2.5
2.5
2.5
2.3
2.8
2.6
2.6
2.3
2.5
2.0
2.0
2.0
2.0
2*0
2.3
4.0
1.8
2*0
2.1
2.1
2.0
1.8
2.0
1 .8
1 .2
1.5
1 .6
2.0
U E GAS
C02 VOL Z
ANAL
14.7
14.7
15.0
14.7
14.7
15.0
14.4
14*4
14.4
15.0
15.0
15.0
15.0
15.0
15.0
14.7
14.7
14.7
14.7
14.7
15.0
15.0
15*0
15.0
15-3
15-0
15.0
13.2
CALC
13.8
13.8
13«8
13.9
13.6
13.7
13.7
13.9
13.8
14.2
13.9
14.2
14.2
14.2
14.0
12.7
14.3
14.2
14. 1
14. 1
14*2
14.3
14.2
14.3
14.8
14.6
14.5
14.2
S02
PPM
1 19.
-
1 19.
119.
119.
12.
12.
10.
16.
16.
9.
9.
9.
9.
9.
9.
9.
9.
9.
55.
55.
37.
1 19.
-
-
-
-
-
REGENERATOR GAS
02
Z
0.10
0.20
0.50
0.40
21.00
0.10
0.10
0.10
0.
0.
0.
0.
0.
0*
0.
0.20
0.20
0.20
0.10
0.
0.
0.40
0.20
0.
0.
0.
0.
0.
C02
Z
2.2
1 .1
2.0
2.0
0.5
1.5
1.7
1 .9
2.5
2.5
3.5
2.2
3-3
3*0
1 .3
1 .4
2.5
2.8
3.1
2.6
2.8
2.5
2.5
2.6
2.5
2.P
1 .7
?»2
S02
Z
4.2
1.2
2.7
3-5
1.5
4.6
3.7
4.2
4.2
3.9
3.3
3.7
5.0
4.6
3.1
3. 1
4.2
3.9
4.6
4.2
4.2
3.9
3.9
4.2
3.9
3.5
3. 1
4.2
GASIFIER INLET GAS
02 VOL Z C02 VOL Z
ANAL CALC ANAL CALC
16.0
16*0
16.0
16.0
16.0
16.0
16.5
16.5
16*5
16.5
16.5
16.5
16.7
17.0
1 7.0
17.0
16.8
17.0
16. 1
16*0
16.0
16.0
16.0
16-1
16.0
1 6.0
16.0
16.0
15-
16.
15.
16.
9
0
9
0
6
5
7
16.1
16.4
16.4
16.5
16-
16.
16.
16.8
16.4
17.0
16.9
17.3
16.7
16.3
16.3
16. 1
16.0
16.3
16.3
16.5
16.2
16.3
16.Pi
3.10
3« 10
2.76
3. 10
2.93
2.93
2.93
2.76
2.76
2.76
2.28
2.76
2.60
2*44
2.44
2.44
2.44
2*44
2.84
2.93
2.84
2.84
2.76
3.82
3.92
3.92
4.03
3.94
4.12
3.94
3.94
3-73
3.58
3-43
3.43
3.57
3.39
3-34
3*60
3-14
3.26
3.22
3-25
3.61
3*66
3.82
3.90
3-64
3-66
3.47
3.72
3.64
3.85
3.45
-------
24.2330
25.0030
25.0130
25.0230
25.0330
25.0430
25.0530
25.0630
25.0730
25.0830
25-0930
25. 1030
25.1 130
25.1230
25- 1330
25.1430
25.1530
l 25.1630
0 25.1730
^ 25.1830
I 25.1930
25-2030
25.2130
25.2230
25.2330
26.0030
26-0130
26.0230
26.0330
26.0430
26.0530
26-PI630
26.0730
26.0*30
26.0930
26. 1030
2.5
2.1
2.0
2.0
2.3
2.3
2.4
2.4
3.0
2.0
2.1
3. 1
2.8
2.2
2- 1
2*9
2.8
2.7
2. 1
2.6
2-2
2. 1
2. 1
2.0
2.0
1 .9
1 .9
?.0
2.2
1 .8
2.0
2.0
1 .6
1 .7
2.0
2.0
1 4. 4
14. 7
15.0
14.7
14.4
14.4
14.4
14.4
13.8
14- 7
14. 4
13.5
13.8
13.8
14.4
14. 1
14. 1
14. 1
14.4
13.8
14.4
1 4*4
14.4
14.4
14.4
14- 7
1 4. 4
14. 1
14. 1
14.4
4.4
4-1
4. 4
4. 1
4*4
1 4.4
1 3-8
14.1
14.2
1 4.2
1 4.0
14.0
13.9
13-9
13.4
14-2
14. 1
13.4
13.6
14. 1
14. 1
13-5
13.6
13.7
1 4. 1
1 3.8
1 4. 1
1 4. 1
14. 1
14.2
1 4.2
14.3
14.3
1 4.2
14. 1
14.4
14.2
1 4.?
1 4-5
1 4.4
14.2
14.2
55.
119.
82.
151 .
100.
73.
64.
100.
77.
137.
64.
-
18.
201 .
100.
137.
137.
173.
137.
137.
192.
1 64.
1 46.
121-
137.
131 •
100.
123.
1 40.
164.
128.
155.
146.
1 10.
137.
1 37.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
PI.
0.
0.
0.
0.
1 .7
1 .6
1 .7
1 .4
2.5
2.2
?. 1
1 .7
2.5
1 -7
1 .9
2.2
2.3
2-2
3.2
2.3
2.5
2.5
2.2
2.3
2.3
2.6
3. 1
2.4
2.7
3-3
3-0
1 .7
1 .7
1 .9
3-3
3-0
2.0
2.8
2.3
2.5
2.7
2.7
2.0
3. 1
4.2
4.0
4.0
4.2
4.2
3-7
3.5
3-9
4.6
4.2
5-0
3.3
3. 1
3.7
4.2
4.2
4.2
3.9
4.2
3.7
3.5
4.6
3.9
2.9
3.5
3.5
4.2
4.6
2.2
3.5
3.7
4.2
1 6.0
16.2
16.3
16.3
16.3
1 6.4
16.4
1 6.4
16.6
16-3
1 6-3
1 6.6
16.7
16.7
16.3
16.5
16.4
16.3
16.3
16.2
16.2
16.2
16.3
16.4
16. 1
15.9
16.0
1 6.0
1 6.7
16.5
16.5
16.3
15. «
16. 1
1 6.1
1 5.8
16.2
16* 1
16-0
16-0
16. 1
16. 1
16.2
16.2
16.3
16.0
16.4
16.8
16.3
16.3
16.6
16.8
16.8
16.8
16.6
16.5
16*6
16.5
16.3
16-3
15.8
15.8
1 6.0
1 5.9
16.6
16.2
16.3
16.3
15.9
16.0
16.2
15.7
3.8?
3.82
3-92
3.R2
3.73
3.73
3-73
3-73
3-54
3.73
3.73
3-54
3.54
3.54
3.73
3- 54
3-63
3.63
3.73
3-82
3.82
3-82
3.82
3-73
3.92
4. 1 1
4.02
4.02
3.54
3.63
3-45
3.63
4. 1 1
3.9?
3.9?
4. 1 1
3.74
3.82
3.90
3.8?
3. 74
3« 74
3.74
3. 74
3.6PI
3.82
3.47
3. 13
3.57
3»44
3.33
3.27
3.27
3.27
3.33
3.35
3.39
3.39
3.57
3.57
3.89
3.97
3.74
3. 74
3.27
3-58
3. 58
3.50
3» 74
3.67
3-64
3-97
-------
RUN 5:
GAS COMPOSITIONS
PAGE 6 OF 6
ro
H-
o
'
DAY. HOUR
26. 1 130
26-1230
26-1330
26-1430
26. 1530
26.1630
26.1730
26. 1830
F L
02
Z
2-0
2-0
2.0
2-0
2.0
2.0
1 .8
2.0
U E GAS
C02 VOL Z
ANAL CALC
14. A
14. 1
14.1
14.4
14. 1
14.4
14-4
14- 1
4.2
4.2
4.2
4-2
4.2
4.2
4.4
4.2
SO?
PPM
100.
137.
137.
1 10.
164.
201 .
201 .
228.
REGENERATOR GAS
02 CO? S02
Z
0.
0.
0.
0.
0.
0.20
0.20
0.
%
3.7
4.3
2.5
2-5
2.6
2.5
3.1
2.5
Z
3.5
4.6
3-9
3.5
3.7
3.5
3.7
3.9
GASIFIER
02 VOL Z
ANAL
1 5.8
16.0
15.8
16.0
16.3
16.3
16.2
16.3
CALC
15.7
15.9
16.3
16.5
16.5
16.6
16.6
16.6
INLET GAS
C02 VOL Z
ANAL
4- 1 1
3.92
3.82
3.92
3.63
3.73
3.63
3.63
CALC
3.97
3.75
3.46
3.39
3-30
3-32
3-29
3.25
-------
- 211 -
-------
RUN 5:
APPENDIX B - TABLE VI
SULPHUR AND STONE CUMULATIVE BALANCE.
PAGE 1 OF 6
DAY. HOUR
2.0130
2.0230
2.0330
2.0430
2.0530
2.0630
2.0730
2.0830
2.0930
2. 1030
2.1 130
2. 1230
2-1330
2. 1430
2. 1530
2. 1630
2. 1730
2. 1830
2.1930
2.2030
2.21 30
2.2230
2.2330
3.0030
3.0130
3.0230
3.0330
3.0430
TOTAL
K I L
IN FLUE
0.139
0.277
0.410
0.543
0.676
0*808
0.941
.077
.220
• 365
-505
.645
• 783
• 922
2.062
2.200
2.337
2.473
2.610
2-747
2.883
3.020
3.151
3.290
3-4??
3.556
0.021
0.045
0.078
0. 103
0. 108
0*111
0.152
0.223
0.302
0.353
0.403
0.460
0.510
0.556
0.597
0.631
0.665
0*698
0-731
0.763
0-803
0.844
0.88?
0.924
0.96?
1 .000
S U L P H U
0 M 0 L S
REGEN FINES
0.031
0.080
0.130
0.175
0*241
0.290
0.326
MISSED
0.352
0.397
0.432
0.454
0.508
0.582
0.646
0.708
0.766
0.831
0.897
0.922
0.962
• 026
.094
-145
MISSED [
• 226
• ?88
• 349
0.007
0.008
0.014
0*023
0.026
0.027
0.032
R
IN-OUT
0.079
0. 144
0.188
0.242
0.301
0*380
0.431
EQUIVALENT BURNT STONE
K ILOGRAMS
FEED REMOVED IN-OUT
19.5
35-7
41.3
41 .3
42.7
44.?
45.2
DATA READING
0.035
0.037
0.039
0.041
0*043
0.046
0.050
0.053
0.056
0.059
0.069
0.071
0.073
0.074
0.077
0.076
0.466
0.485
0.541
0.608
0.633
0.645
0.671
0.704
0.747
0.781
0.810
0.886
0.950
0.980
1 .006
1 .047
DATA READING
0.076
0.0RR
0.093
1 .064
1 .08/i
1.113
47.2
50. 1
53.4
56.5
60. 1
64.2
68.5
73-2
77.5
8?. 7
87.8
92.4
97.0
101 . 7
106. R
112.4
117.6
127.9
8.8
*.* • \t
10.8
18.2
28.5
31*3
32.7
37.2
40. 3
41 .9
43. 5
45* 1
47. 1
-^ • • 1
49 . |
52.8
56.3
59. 4
60.9
74. 6
76. 1
77. PI
77.9
R0. 4
R0. 1
79 .9
R6. 3
SR.7
10.7
I r ' . f
24 .8
23. 1
12.8
1 1 • S
1 1 " -J
11*4
* I * M
8.0
6*9
\J • r
8 . ?
u • c.
9.9
11*4
• i • •*
11.0
1 *J • Tt
15.1
I *J * I
15.7
V >^ • 1
16*8
•I Vr * tJ
1 R . ?
I r i • C,
Pi .R
e. i • o
13.?
1
-------
3.
3.
3.
3.
3«
3»
3.
3.
3.
3.
3.
3.
3-
3-
3.
3.
3.
I 3.
to 3.
c *•
A.
4.
4.
4.
4.
4*
4.
4.
4*
4*
4.
4.
4.
4.
4*
0530
0630
0730
0830
0930
1030
1130
1230
1330
1430
1530
1630
1730
1830
1930
2030
2130
2230
2330
0030
0130
0230
0330
0430
0530
0630
0730
0830
0930
030
1 30
230
330
430
530
3.694 1.040
3.832 1.077
3.969
4. 107
4.242
4-378
4.515
4.651
4.789
4.926
5.059
5. 191
5.317
5.463
5.592
5.744
5.881
6.018
6.155
.1 16
.146
. 1 74
• 21 1
.243
.277
.308
• 350
.387
• 420
.462
.402
.455
• 516
.576
.639
• 690
.718
.761
.773
• 838
.881
.934
.975
.511 2.032
.565 2.086
.630 2.102
.688 2.113
.742 2.172
.807 2.192
6.287 1.880 2-245
0.098
0.103
0.109
0.113
0. 1 18
0.123
0.128
0.136
0.144
0.160
0.174
0.186
0.199
0.204
0.210
0.214
0.219
0.223
0.227
0.233
STONE CHANGE
6.425 1.921 2.309
6.564 1.963 2.390
6.696 2.001 2.452
6.831 2.039 2.515
_
6.978 2.077 2.554
7.121 2.101 2.635
7.263 2.154 2.710
_
7.399 2-186 2.786
_
7.538 P. 237 2.829
0.277
0.283
0.289
0.294
.153
.196
.229
.271
.31 1
• 354
.426
.477
.564
.577
.617
• 651
.682
.714
.732
.798
.862
• 881
.929
.928
.918
.929
.954
.983
-
0.300 2.047
0.305 2.080
0.311 2.089
-
0.33? 2.096
-
0.347 2.124
132.5
136.6
141 .5
146*3
151.5
155-3
158.7
162.0
165.6
169.8
173.8
177.4
181.8
187.2
191 .8
196.7
202.0
205.4
205.4
205.4
205.4
205.4
205.4
205.4
234.8
274.5
306.6
323.2
328.*
3PR.R
328. 8
343. P!
91.2
93.6
96. 1
98.3
100.5
102.8
105.0
108.3
111.5
128.8
144.9
158.5
173.6
175.8
177.9
179.3
180.7
182.1
183.6
185.7
253.4
255.6
257.8
260.0
262-3
264.5
266. P
269. PI
271.3
291.5
29 3 • 9
310.7
41 .3
43.0
45* 4
48.0
50-9
52.6
53.7
53. 7
54. 1
41 . 1
28-9
18.9
8.2
11.4
13.9
17.3
21 .3
23-2
21 .8
19.6
-48.0
-50.2
-52.4
-54.6
-27.4
10.0
39.8
54.2
57.4
37.3
34.9
32.3
MISSED DATA READING
7.676 2.P43 2.904
7.816 2.277 2.967
0.366 2.163
0.377 2.195
361 . 4
3SP.4
335.5
348.6
P6.PI
31. R
-------
RUN 5: SULPHUR AND STONE CUMULATIVE BALANCE.
PAGE 2 OF 6
DAY. HOUR
4*1630
4*1730
4.1830
4.1930
4.2030
4.2130
4.2230
4.2330
5*0030
5.0130
5*0230
5.0330
5*0430
5.0530
5.0630
5.0730
5.0830
5.0930
5. 1030
5-1 130
5.1230
5.1330
5.1430
5.1530
5.1630
TOTAL
K I L
IN
7.955
8.094
8*234
8*375
-
-
-
8*51 1
8*657
8.789
8.925
9.072
9.213
9.354
9.493
9.634
9*776
9*917
10*057
10*196
10*331
10*465
10.599
FLUE
2*315
2*340
2*348
2*361
"-
-
-
2*379
2*396
2.408
2*410
2*424
2*441
2*450
2.455
2*462
2*471
2*481
2*489
2*501
2*516
2*526
2*533
S U
0 M
L P H U
0 L S
REGEN FINES
3*016
3*053
3*135
3*202
-
-
-
3*275
3-365
MISSED
3*389
3*404
3*468
3*521
3*584
3*645
3*71 1
3*790
3*862
3*937
4*009
MISSED
4.085
4*159
4*220
0*388
0*398
0*403
0*416
-
-
-
0*423
0*436
R
I N-OUT
2*236
2.303
2*348
2*395
-
-
-
2*434
2*461
EQUIVALENT BURNT STONE
KILOGRAMS
FEED
398.5
416.3
439.0
463.8
486.5
503-8
521.3
539.6
560.9
REMOVED 1
361 .8
374.6
376.8
392-3
408.5
425*9
444*5
448*5
467.4
N-OUT
36.7
41 .7
62*2
71*5
78*0
77.9
76*8
91 .2
93.5
DATA READING
0*434
0*440
0*467
0.480
0.494
0.506
0.520
0.533
0*549
0*555
0*559
2*558
2*672
2*713
2.771
2*826
2*887
2*940
2*982
3-026
3.076
3* 128
579.3
598.0
617.5
636-2
654.5
669.1
688. 1
712.6
732-3
750.9
763.2
466*3
478*4
497*9
516*4
534*5
551*6
568*8
584*6
604* 7
609*7 1
613.4
13*0
19*5
19*6
19*8
20.0
17.6
19.3
27.9
27.6
41 .3
49*8
DATA READING
0.564
0.569
0.572
3*166
3*21 1
3*275
771 .9
780.4
790.6
618.4 1
623.5 ]
625.5 !
53*5
56*9
65*1
6
6
.0230
.0330
SHUT DOWN AT 5*1630 FOR 10 HOURS
10.732
10.865
2.565
2.587
4
4
271
328
0
0.
57?
57?
3-
3.
324
799*9
K14.P
625*7
625.9
1 74*3
188.4
-------
I
NJ
6*0430
6.0530
6-0630
6.0730
6.0830
8.2230
8.2330
9.0030
9.0130
9.0230
9.0330
9.0430
9.0530
1 -1430
1 .1530
. 1630
• 1730
. 1830
• 1930
.2030
1 .21 30
! .2230
1 .2330
2.0030
2.0130
1 1 .000
1 1 -133
1 1 .266
1 1 -399
1 1 .527
SHUT DOWN
-
1 1 .662
-
1 1 .801
1 1 . 9 40
-
12.077
12.214
SHUT DOWN
12.354
12.501
12.638
12.775
12.911
13.048
13-185
13.321
13.460
13.600
13.743
2.602
2*611
2.614
2.618
2.621
AT 6.
-
2-655
-
2.687
2.703
-
2.720
2.746
AT 9.
2.783
2.808
2-832
2.856
2.865
2-871
2-882
2.909
2-931
2.966
3.006
M
4.370
4.421
4.485
4.546
4.621
0.573
0.573
0.573
0.573
0.574
3.455
3.528
3.594
3.661
3.711
0830 FOR 62 HOURS
-
4.631
-
4-657
4.684
-
4.739
4.81 1
_
0.574
-
0.574
0.574
-
0.574
0-575
_
3.802
-
3.884
3.979
-
4.043
4.083
0530 FOR 57 HOURS
4.852
4.871
4-928
4.963
5.041
5.097
5.180
5.246
5.324
5.402
5.498
0.575
0.575
0.575
0.575
0.575
0.576
0.574
0.574
0.575
0.580
0.581
4* 145
4.246
4.303
4.380
4.429
4.504
4.548
4-592
4.630
4.652
4-658
ISSED DATA READING
827.9
841 .4
853.0
864.4
876.3
892.1
908. 1
928.8
950.4
969.7
986.9
999.4
1009.3
1034.7
1058.9
1069. 1
1 0 79 . 3
1090.4
01 .5
12.9
25.7
38.0
51.4
66. *
626. 1
626.3
626.5
626.7
626.9
630.0
630.2
630.4
630.6
630.8
631 .0
631 .2
631 .4
631 .6
631 .8
632.0
632.2
632.4
632.6
631-5
631 -7
631 .9
642.6
642. R
201 .9
215. 1
226.6
237.7
249.5
262. 1
277.9
298.4
319.8
338.9
355.9
368.2
377.9
403- 1
427. 1
437. 1
447. 1
458.0
468.9
481 .4
494-0
506-1
508-8
524.1
-------
RUN 5: SULPHUR AND STONE CUMULATIVE BALANCE.
PAGE 3 OF 6
to
DAY. HOUR
12.0330
12*0430
12.0530
12.0630
12.0730
12*0830
12-0930
12.1030
1 2 . 1 1 30
12.1230
12.1330
12*1430
12.1530
12. 1630
1 2 • 1 7 30
12.1830
12.1930
12.2030
1 2 . 2 1 30
12.2230
12.2330
13.0030
13.0130
13.0230
13.0330
13.0430
13-0530
13.0630
T 0
K
IN
13.884
14.030
14.171
14.313
14.450
14.584
14.720
14.858
T A L
I L
FLUE
3.035
3.063
3.089
3.129
3*160
3.188
3-213
3.238
S U L
0 M 0
REGEN
5.577
5.674
5.735
5.81 1
5.893
5.968
6.036
6.095
P H U
L S
FINES
0.597
0.597
0.597
0.598
0.596
0.596
0*595
0.632
R
IN-OU'
4.675
4.696
4.750
4.776
4*801
4.832
4-875
4.892
MISSED DATA READING
14.996
15-134
15*272
1 5*410
15.549
1 5 • 68 7
15.824
15*961
16.099
16.236
16.377
16.516
16.654
16.790
16.926
17.063
17.200
17.335
17.470
3.264
3.286
3*308
3.331
3.354
3.376
3.397
3-418
3.442
3.470
3.503
3*533
3*559
3.586
3.607
3.634
3.651
3.666
3.682
6*148
6.220
6.278
6.357
6.41 1
6*490
6.553
6-624
6.696
6.755
6.830
6.899
6.964
7.030
7.109
7.178
7.24R
7.327
7.375
0.632
0*662
0*675
0*677
0*679
0.680
0.682
0*684
0* 760
0.761
0. 770
0.777
0*781
0.786
0.789
0.791
0.794
0*796
0.941
4*951
4*965
5.01 1
5*046
5.106
5. 141
5. 192
5-235
5.201
5.250
5.275
5.307
5.349
5.388
5-421
5-461
5-506
5.547
5.472
EQUIVALENT BURNT STONE
K ILOGRAMS
FEED REMOVED IN-OUT
1175.0
1 182*0
1191.1
1201*0
1208.0
1217.9
1231.9
1245.0
1257.3
1269.2
1 28 1 - 3
1295-0
1308.2
131R.1
1329.4
1341.7
1352.8
1364.9
1376.4
1386.6
1398.9
1410.5
1420.4
1430.4
1440.4
1 448 • 6
1458.2
689.2
689.4
689.7
689.9
688.8
689.1
688-0
740.6
741 .0
764.2
773-9
775.8
777.7
779.7
781 .6
783.5
850.7
852.6
866.6
876.2
882.0
887.8
890. R
893. R
897.2
899.7
107«.0
485.8
492.6
501 .4
511.1
519.
528.
543«
504.
1
>8
9
4
516.2
505.0
507.5
519.2
530.4
538.4
547.9
558.2
502. 1
512.2
509.8
510
516
522
529
536
543.?
548.9
380.2
-------
SHUT DOWN AT 13.0630 FOR 73 HOURS
16
16
16
16
16
16
16
16
16
16
16
16
16
16
16
1 16
to 16
5 17
1 17
17
17
17
17
17
17
17
17
17
17
17
17
17
•
•
•
•
•
•
•
*
•
•
*
•
•
•
*
•
•
•
•
•
•
•
•
•
•
•
*
•
•
•
*
•
0730
0830
0930
1030
1 130
1230
1330
1430
1530
1630
1730
1830
1930
2030
2130
2230
2330
0030
0130
0230
0330
0430
0530
0630
0730
0830
0930
1030
1 130
1230
1 330
1 430
-
17.606
-
17.742
17.878
18.01 5
18. 151
18.286
18.421
18.557
18-692
18-827
18-962
19.104
19.246
19.383
19-521
-
-
-
-
-
-
-
19.659
19.798
19.937
20.077
20.216
20.361
-
3.731
-
3.768
3-802
3.846
3.881
3.915
3.949
3.983
4.013
4.019
4.022
4.024
4.026
4.027
4.030
-
-
-
-
-
-
-
4.047
4.070
4.098
4.126
4. 149
4.191
-
7.393
-
7.449
7.496
7.548
7.619
MISSED
7.667
7.728
7.806
7.891
7.960
8.048
8.069
8.131
8-182
8.242
-
-
-
-
-
-
-
MISSED
8.309
8.374
8-456
8-529
8.605
8.676
-
0.
-
0.
0.
0.
0.
943
961
964
968
971
-
5.538
-
5.564
5.616
5.653
5.681
1469.6
1 48 5 • 9
1502.0
1516.3
1529.4
1547.2
1565.5
1080-4
1083-3
1 1 13-0
1 142.7
1 146. 1
1 152-8
1 156. 1
389-2
402.6
388.9
373-5
383.3
394.4
409.5
DATA READING
0.
0.
0.
0.
0.
0.
0.
1 .
1 •
1 •
-
-
-
-
-
-
-
DATA
1 .
1 .
1 .
1 •
1 .
1 •
973
974
976
978
981
985
988
019
023
027
5.732
5.770
5.792
5-810
5.867
5.907
6.023
6.071
6. 151
6.222
-
-
-
-
-
-
-
1583.0
1602.0
1622.4
1644.9
1666.7
1688.0
1709.3
1730.9
1740.8
1751 .3
1761 .0
1770.9
1782.5
1 79 1 . 3
1804.4
1816. 1
1828.0
1 1 59 . 3
1 161 .3
1 164.5
1 167.8
1 171.9
1 176.9
1 181 .9
1203.3
1209.2
1215-1
1 22 1 . 0
1227.0
1233. 1
1239.3
1250.4
1255.3
1260.3
423.7
440.7
457.9
477. 1
494.8
511.1
527.5
527.6
531 «6
536.2
539.9
543.9
549.4
552.0
554.0
560.7
567.7
READING
029
033
036
039
042
045
6.274
6.321
6.347
6.383
6.420
6.449
1832.5
1845.9
1856.9
1867.7
1880.5
1895- 1
1264.0
1268.9
1273.9
1278-1
128?. 2
1286.4
568.5
577.0
583.0
589.6
598.3
608.7
-------
RUN 5: SULPHUR AND STONE CUMULATIVE BALANCE.
PAGE 4 OF 6
t
N)
M
OD
I
T
DAY. HOUR
17. 1530
1 7. 1630
17. 1730
17. 1830
17. 1930
17.2030
IN
20.501
20.64?
20.781
20.920
21 .058
21 . 196
0 T A L
K I L
FLUE
4.230
4.250
4.289
4.315
4.338
4.350
SHUT DOWN AT 17
20.2030
20.21 30
20.2230
20.2330
21 .0030
21 .01 30
21 .0230
21 .0330
21 .0430
21 .0530
21 .0630
2! .0730
21 .0830
21 .0930
21 . 1030
21 • 1 130
21 .1230
21 • 1330
21 . 1430
21 .1530
21 .343
2 1 . 49 3
21 .648
21 .806
21 .964
22. 1 12
22.272
22.435
22.596
22.757
22.917
23.077
23.240
23-397
23-557
23.717
23.877
24.037
24.197
24-358
4.358
4.363
4.371
4.376
4.379
4.381
4.383
4.388
4-389
4.390
4.401
4.413
4.426
4.438
4.458
4.46?
4.468
4.483
4.497
4.506
SULPHUR
0 M 0 L S
REGEN FINES
8.742 .048
8.781 .051
8.840 .064
8.917 .445
8.984 .449
9.054 .454
STONE CHANGE
.2030 FOR 72
9.094
9.119
9.171
9.230
9.288
9.345
9.386
9-434
9.492
9.563
9.621
9.667
9.731
9.788
9.838
9.896
• 459
.466
-480
• 484
-496
-500
.504
.509
.513
• 519
.52?
• 525
• 529
• 545
.550
.555
9.960 1.557
10.020 1 .598
10.083 1 .600
10-133 1.607
IN-OUT
6.481
6.560
6.588
6.243
6.288
6.339
HOURS
6.43?
6.543
6-627
6.715
6.801
6.887
6-999
7. 105
7.20?
7.285
7.373
7.471
7.554
7.627
7.71 1
7.803
7.892
7.936
8.017
8-113
EQUIVALENT BURNT STON
K I
FEED
1915.2
1935.0
1 9 49 . 3
1961 .9
1973.5
1984.0
2006.6
2019.7
2034.9
2050.3
2064.9
2078.5
2092.9
2103.7
21 16.0
2 1 28 . 3
2 1 39 . 1
2150.7
2162.?
? 172.0
2183.0
2194.6
2206.4
2219.5
?231 .8
??45. 1
L 0 G R A
REMOVED
1290.5
1294.7
1 318.?
1754-4
1759.2
1765.3
1771 .4
1782.0
1794. 7
1802. 1
1813-6
1820. 1
1826.5
1833-6
1840.6
1851 .6
1855.9
I860.?
1867. 1
1886. 1
1893. R
1901 .6
1904.4
1935.4
1938.?
1949.5
M S
IN-OU
6?4. 7
640 . 4
631 .?
207-4
214.3
218.8
235.3
237. 7
240.?
248 .2
251 .3
258 .5
266.4
270. 1
275.4
276.8
283.?
290. 4
295. ?
285.9
289.2
293.0
302.0
284.0
293. 6
?95.6
-------
21 •
21 .
21 .
21.
21.
21 .
21 .
21 .
22.
22.
22.
22.
22.
22.
22.
22.
22.
1 22.
w 22.
£ 22.
22.
22.
22.
22.
22.
22.
22-
1630
1730
1830
1930
2030
2130
2230
2330
0030
0130
0230
0330
0430
0530
0630
0730
0830
0930
1030
1 130
1230
1330
1430
1530
1630
1730
1830
24.520
24.681
24.841
25.001
25.150
25.291
25.434
25-576
25.717
25.859
25.999
26. 140
26.284
26.429
26.568
26.705
26.850
26.991
27.132
27.272
27.413
27.557
27 . 69 7
27.837
27.978
28. 118
28.258
4.510
4.526
4.547
4.569
4-586
4.608
4.632
4.647
4.667
4.678
4.686
4.705
4. 720
4.735
4.748
4.761
4.773
4.787
4-803
4.821
4.839
4.870
4.900
4.929
4.947
4.969
4.992
10.209
10.267
10.339
10.417
10.473
10.524
10.574
10.627
10.674
10.735
10.786
10.850
10.907
10.971
1
1
1
1
1
1
1
1
1
1
1
1
1
.040
.091
. 162
.213
.252
• 304
.355
.427
• 490
.554
.600
.662
.702
.609
.622
.625
.627
.630
.633
.635
• 638
• 642
.645
.649
.653
• 656
.659
• 663
• 665
.668
.674
.678
.683
• 686
.689
• 692
.698
.701
.736
.739
8- 192
8-267
8.329
8-388
8.461
8.526
8.593
8.664
8.733
8.801
8.879
8.932
9.001
9.063
9. 1 18
9.187
9.247
9.317
9.399
9.465
9.533
9.571
9.615
9.657
9.730
9.751
9.825
2258.2
2271 .6
2284.7
2298.8
2307. R
2313.7
2321 .4
2331 .7
2344.0
2355.8
2363.8
2373.3
2381 .0
2388.7
2396.9
2405.1
2414.3
2423.6
2431 .8
2439-2
2447.4
2456.2
2463-6
2471 .3
2480.6
2488.3
2497.3
1953-2
1967.7
1971 .1
1974.5
1977.9
1981 .4
1984. R
1988.9
1993.4
1997.9
2002.4
2006.9
201 1 >8
2017.0
2022. 1
2026.2
2029.0
2034.9
2042.2
2050.9
2054.7
2058.6
2062.5
206R.7
2072.6
2 1 38 . 2
2141 .0
305.0
303.9
313.6
324.3
329. R
332.3
336.6
342. R
350.6
357.9
361 .3
366.3
369.2
371 .7
374.7
378.9
385.3
388.6
389.6
388-4
392.7
397.6
401 .2
402.6
40R .0
350. 1
356-3
SHUT DOWN AT 22.1830 FOR 23 HOURS
23
23
1 730
1830
28
28
393
532
5-
5«
022
037
1 1
1 1
726
76R
742
750
9.904
9.976
2515.5
2534.?
2143.7
2149.9
371 .7
384.4
-------
RUN 5s SULPHUR AND STONE CUMULATIVE BALANCE.
PAGE 5 OF 6
DAY .HOUR
23.1930
23.2030
23.2130
23-2230
23.2330
24.0030
24.0130
24.0230
24.91330
24.0430
24.0530
24.0630
24.0730
24.0830
24.0930
24. 1030
24. 1 130
24. 1230
24.1330
24. 1430
24.1530
24. 1630
24. 1730
24- 1830
24. 1930
24.2030
24.2130
24.2230
T 0
K
IN
28.667
-
28.803
28.939
29.074
29 . 2 1 0
29.348
29.486
29.626
29.765
29.906
30.046
30. 187
30.327
30.467
30.607
30.744
30.884
31 .024
31 .164
31 .304
31 .444
31 .583
-
-
-
-
-
T A L
I L
FLUE
5.049
-
5.061
5.072
5.084
5.085
5.086
5.087
5.089
5.090
5.091
5.092
5.093
5.094
5.095
5.096
5.097
5.098
5-099
5. 104
5-109
5. 1 13
5.1?5
-
-
-
-
-
S U L P H U
0 M 0 L S
REGEN FINES
11.827 1.75R
-
1 1 .862
11 .907
1 1 .930
1 1 .990
12.037
12.093
12. 148
12. 199
12.243
12.292
12.361
12.422
12.460
12.499
12.556
12.608
12.672
12.731
.766
• 774
.783
• 793
• 803
.814
• 826
• 838
• 848
• 858
• 868
• 889
• 91 1
.924
.937
.949
.960
.97?
12.787 2.022
12.841 2.026
12.894 2.029
-
-
-
-
-
R
IN-OUT
10.033
-
10.1 15
10.185
10.277
10.342
10.421
1 0 . 49 1
10.562
10.638
10.723
10.803
10.865
10.92?
1 .002
1 .088
1 .154
1 .229
1 .293
1 .357
1 .386
1 .464
1 .535
-
-
-
-
-
EQUIVALENT BU
K I
FEED
2553.0
2570.2
2587.4
2605.3
2623.3
2641 .3
2659.3
2677.5
2694.4
2710.9
2728. 1
2744.2
2760.7
2780.7
2800.7
2818.4
2836.7
285?.. 1
2857.4
2865.2
?874.9
2885.2
2897.2
2909. 1
?92?.4
29 3 4 . 7
2946.8
?96Pi. 1
L 0 G R
REMOVE
2156.0
2162.?
2 1 68 • 4
2174.5
2182.3
2190.0
2197.7
2207.1
2216.5
?226.0
2?33*9
2241 .8
2249.7
2?68. 1
2286.5
??97.d
2307.5
231 7.2
?3?5.«
?335.7
2375.9
?37<=!.9
?381 .9
2385.0
?3R8.0
2396. 1
?406.4
?41 6.4
A M S
) IN-OUT
397.0
408.0
419.0
430.8
441 . 1
451 -3
461 .6
470.4
477.9
484.9
494
502
510
512
51 4.
521 -
529,
534.
531 •
529 .
499.
506.
515.
524.
534.
538.
?
4
?
8
6
4
1
3
3
1
4
6
543.7
-------
24.
25.
25.
25.
25.
25.
25.
25.
25.
25-
25.
25.
25.
25.
25-
25.
25.
' 25.
10 PS.
lo 3
M 25.
I 25.
25.
25.
25.
25.
26-
26.
26.
26.
26.
26.
26.
26.
26.
26.
26.
2330
0030
0130
0230
0330
0430
0530
0630
0730
0830
0930
1030
1 130
1230
1330
1430
1530
1630
1730
1830
1930
2030
2130
2230
2330
0030
0130
0230
0330
0430
0530
0630
0730
0830
0930
1030
31 .722
31 .862
32.001
32.140
32.279
32.417
32-555
32.693
32.831
32.968
33. 106
-
33.243
33.382
33-519
33.658
33.796
33-933
34.075
34.215
34.355
34.496
34.637
34.777
34.91 7
35.057
35. 197
35.338
35.478
35.618
35.759
35.899
36.039
36. 179
36.319
36.460
5.130
5. 142
5.150
5.164
5.174
5. 181
5.188
5. 198
5.205
5.219
5.225
-
5.227
5.246
5.256
5-270
5.284
5.301
5.314
5.328
5.347
5.363
5.378
5.390
5.403
5.416
5.426
5-438
5.451
5.467
5.480
5-495
5.509
5.520
5.533
5.546
12.930
12.969
12.996
13.037
13.097
13.154
13.21 1
13.271
13.331
13.382
13.430
-
13.496
13.555
13.625
13-667
13.709
13.760
13.820
13-879
13-937
13.990
14.048
14.098
14. 1 44
14.207
14.260
14.299
14.347
14.396
4.458
4.525
4.555
4.605
4.656
4.716
2.041
2.054
2.067
2.079
2.091
2.103
2.116
2.127
2- 139
2.151
2.163
-
2-176
2.184
2.199
2*206
2.219
2.250
2.258
2-272
2.281
2.289
2-298
2.308
2-319
2.330
2.340
2-352
2.364
2-373
2-381
2.391
2.401
2.410
2-421
2.429
1 .620
1 .697
1 .788
1 .859
1 .917
1 .978
12.040
12.097
12. 155
12.216
12.288
-
12.345
1 2 • 39 7
12.439
12.515
12.584
12.622
12.682
12.735
12.790
12.853
12.913
12.981
13-051
13- 105
13. 1 72
13.249
13-315
13.382
13.440
13.488
13.574
13.645
13.710
13.769
2971.
2985.
2998.
301 1.
3025.
3035.
3046.
3059-
3070.
3082.
3094-
3107-
3117.
3129.
3140-
3151 •
3160.
3171.
3179.
3188.
3196.
3205-
3213.
3222-
3232.
3241-
3249.
3258.
3266-
3275-
3283.
3290.
3301 •
3312.
3322.
3333.
7
0
9
7
1
4
9
5
3
9
4
0
0
1
6
4
9
9
6
1
3
6
5
8
0
3
5
5
7
4
6
6
6
9
6
7
2426.
2436-
2446-
2455.
2464.
2475-
2485-
2494.
2503-
2512.
2523.
2532-
2542.
2549.
2561.
2566.
2576.
2592.
2598.
2607.
2613.
2618.
2624.
2631.
2639.
2646.
2653.
2662.
2671.
2677.
2684.
2691 .
2699.
2707.
2716.
27??.
0
1
2
6
9
2
0
3
5
9
0
9
8
1
8
6
8
9
3
5
1
7
3
8
5
7
8
8
5
8
1
9
7
1
1
2
545.7
549-0
552-7
556.2
560- 1
560.2
561 .9
565.2
566.7
570.0
571 .5
574.1
574.2
580.0
578.8
584.8
584. 1
579.0
581.4
580.7
583-3
586.9
589.3
591.0
592-5
594-6
595.7
595.7
595- 1
597.6
599.5
598.7
601.9
605.8
606.5
611.5
-------
to
N)
ro
RUN 5» SULPHUR AND STONE CUMULATIVE BALANCE.
PAGE 6 OF 6
DAY. HOUR
26.
26.
26.
26.
26.
26.
26.
26.
BYE
0116
1 130
1230
1330
1430
1530
1630
1730
1830
• 38
I
36.
36-
36.
37.
37.
37.
37.
37.
CRU
OFF AT 14:21
TOTAL
K I L
N
601
741
881
021
161
302
442
582
FLUE
5.556
5.570
5.583
5.594
5.610
5.630
5-649
5.671
0002-84
S U L P H U
OM 0 I
-------
APPENDIX B - TABLE VII
ANALYSIS OF SOLIDS REMOVED DURING RUN 5
TOTAL SULPHUR WT.Z
DAY.HOUR GAS'R REGEN REGEN ELUTR BOILER BOILER ELUTR
CYCLONE FINES BACK FLUE COARSE
3. 1530
3.2200
5*1045
6.0730
12.1600
12*1800
13.0400
13.0600
17.1 130
17.1800
21.0700
21 .1800
22.0715
22.1745
25.0530
25.1400
26.0400
26*1000
26*1800
2.77
2.72
3.57
3-72
2.92
3.05
2.66
2.55
3*20
3.64
2.67
2.91
2.86 !
2.92
2.61
2.52
2.81 '
2.79
2.83
.82
• 81
.59
• 84
• 85
• 80
>.06
• 83
.00
-
1.78
1 .75
>.21
.91
.88
.72
2.17
.96
.96
-
8.1 1
4.59
4.69
4.78
4.59
2.14
4.21
4.24
5.11
5.19
5.82
6.21
6.62
5.75
5.79
5.93
5.88
6*10
7.85
7.17
4.97
2.34
-
4.41
4.66
4.03
5.12
4.81
5.82
5-57
6.70
6*30
6-89
6*94
4*94
2.35
6.47
5.15
4.99
3.34
3.38
3.26
3.70
3.69
3.50
2.88
4.03
4.27
4.52
5. 16
4.62
3-85
4.08
4. 10
4.30
4.90
6.44
8.04
1 .96
1 .74
3.26
2.96
1.68
1.75
1 .44
1.56
2.94
3-59
3-53
3.36
3.08
3. 14
3.57
3.54
3-37
4.26
8.39
-
5.24
4.56
3.72
5.13
3-57
4.40
4.92
6. 12
7.28
7.45
7.09
7.86
6.21
6.94
6.68
7.46
- 223 -
-------
APPENDIX B - TABLE VIII
ANALYSIS OF SOLIDS REMOVED DURING RUN 5
SULPHATE SULPHUR WT.*
DAY-HOUR GAS'R REGEN REGEN ELUTR BOILER BOILER ELUTR
CYCLONE FINES BACK FLUE COARSE
3.1530
3*2200
5.1045
6.0730
12.1 600
12.1800
13*0400
13*0600
1 7 . 1 1 30
17.1800
21 .0700
21 .1800
22.0715
22.1745
25.0530
25.1400
26.0400
26*1000
26. 1800
0.23
0*38
0.40
0.28
0.40
0.35
0.35
0.35
0.29 (
0.22
0.36 1
0.19 f
0.48
0.43
0.39
0.44
0*35
0.39
0.34
.27
. 19
• 29
• 48
.12
• 18
.33
.28
1.80
-
1.19
9.80
.29
.26
.35
.12
.37
.26
.27
-
4.63
3.48
3.40
3.47
2.91
1 .28
2.71
3.07
3.17
3-27
2.99
4.25
4.55
3.83
3*68
4.00
3.83
4.1 1
3-85
0.25
0.32
0.46
-
0.30
0.29
0.37
0*25
0.29
0.35
0.36
0.71
0.66
0.20
0.55
0.32
0.36
0.39
I .88 J
3.20
1 .74
2*1 1
2.58
2.93
2.44
1 .96
2.56
.41
• 18
.37
.71 J
• 66 ?
2.24 £
1 .40 i
2.31 J
1.47 J
2.19 f
2.62
• 65
.53
• 57
.71
.51
.34
• 34
.24
.26
.94
.79
>.09
>.26
>*04
?.30
>.31
?.22
>.19
0.32
0. 17
-
0.31
0.25
0.23
0.?8
0.25
0.27
0.28
PI. 24
0.?1
0.48
0.44
0.26
0.41
0.27
0.32
0*36
- 224 -
-------
APPENDIX B - TABLE IX
ANALYSIS OF SOLIDS REMOVED DURING RUN 5
TOTAL CARBON WT.%
DAY.HOUR GAS'R REGEN REGEN ELUTR BOILER BOILER ELUTR
CYCLONE FINES BACK FLUE COARSE
3.1530
3.2200
5« 1045
6.0730
2>1600
2. 1800
3.0400
3.0600
7.1 130
7. 1800
21 .0700
21 . 1800
22.0715
22. 1745
25.0530
25.1400
26.0400
26.1000
26. 1800
0.
0.
0.01
0.05
0.12
0.10
0.09
0.06
0.08
0.21
0.
0.14
0.
0.04
0.
0.02
0.02
0.03
0.02
0.
0.02
0.
0.
0.04
0.
0.
0.
0.
0.50
0.
0.
0.
0.
0.
0*
0.06
0.
0.
-
2.81
0.
0.09
0.46
0.08
-
0.45
0.11
0.02
0.
0.07
0.20
0.05
0.04
0.
0.19
0.07
0.
19.97
26.05
1 .51
3. 18
-
2.49
2.71
2.91
0.87
1.79
8.54
9.19
5.56
5.78
2.35
4.51
5-85
5.91
5*14
0.32
0.07
0*12
0. 17
0.14
0.
0.05
0.19
0.
0.03
0.43
0.56
0.13
0.29
0.
0.
0.
0.19
0*12
8.83
9.09
0.27
0.65
0.50
0.52
0.45
0.55
0.15
0.24
3.21
2.90
1 .61
0.65
0.41
0.50
1 .66
0.
0.89
! .41
9.47
-
1 .73
PI. 92
0.50
1 .20
0.38
0.36
0.55
2.35
3.91
2.82
2.67
1 .49
1 .26
1 .99
1.73
2.37
- 225 -
-------
APPEHDIX B - Table X
Urn Metals Content (Run 5)
Tim
D»Ti Hour
3.1550
3.2200
5.1045
6.0730
12.1600
12.1800
13.0400
13.0600
17.1130
17.1800
21.0700
21.1800
22.0715
22.1745
25.0530
25.1400
26.0400
26.1800
Sampling
Position
Oasifler Lower
Oasifler Upper
Regenerator
Oasifler Lower
Regenerator
Oasifier Lower
Oasifier Upper
Regenerator
Oasifier Lower
Regenerator
Oasifler Lower
Oasifier Upper
Regenerator
Oasifler Lower
Oasifier Upper
Regenerator
Oasifler Lower
Oaaifier Upper
Regenerator
Oasifier Lower
Oasifler Upper
Regenerator
Oasifier Lower
Oasifier Upper
Regenerator
Gasifler Lower
Oasifler Upper
Regenerator
Oasifier Lower
Oasifler Upper
Regenerator
Oasifler Lower
Oasifler Upper
Regenerator
Oasifler Lower
Oasifler Upper
Regenerator
Oasifler Lower
Oasifier Upper
Regenerator
Oasifler Lower
Oasifier Upper
Regenerator
Oasifler Lower
Oasifier Upper
Regenerator
Oasifier Lower
Oasifier Upper
Regenerator
Oaaifier Lower
Oasifler Upper
Regenerator
Vanadium
ppm
5000
- 4800
4200
4900
6000
3200
4000
3400
4400
5000
2600
2500
2000
2800
2700
2800
3100
3200
4200
3100
3100
3600
1700
2000
1300
2800
2300
3000
2200
1900
2500
2900
3300
3600
4200
4700
5300
6300
5700
5300
5100
5000
5700
5000
5800
5400
6100
6300
6500
5700
5800
5600
Sodium
ppm
259
296
375
215
392
494
522
540
530
541
369
361
330
300
317
317
466
469
510
425
492
487
330
415
300
415
430
505
205
185
195
245
215
255
295
295
280
275
320
280
280
245
235
345
230
245
180
155
240
195
185
245
Nickel
PPBl
477
454
451
449
653
454
434
44C
552
622
376
363
301
413
337
351
326
360
470
349
354
363
325
280
265
320
320
360
255
266
315
365
420
406
365
405
470
545
495
480
500
470
625
465
495
475
540
500
620
561
520
580
- 226 -
-------
APPENDIX B - TABLE XI
Calcium Oxide and Silica Contents of Bed during Run 5
Sampling Position:
Time
Day, Hour
5.1045
6.0730
12.1630
12.1800
13.0400
13.0600
17.1130
17.1800
21.O700
21.1800
22.O715
22.1745
25.0530
25.1430
Gasifier
Uoyer
CaO
Wt %
76.3
-
75.1
74.5
73.6
76.4
-74.5
75-8
86.7
87.8
87.4
87.8
-
-
aio
wt %
15.4
-
17.2
17.2
16.1
18.4
16.1
15-3
5.0
4.7
4.2
3.3
-
-
Gasifier
Lower
CaO
Wt*
73-6
74.5
75.3
76.3
75.5
75.6
79.7
79.*
89.7
84.7
85.8
87.1
96.3
97.1
S109
Wt£
15.0
17-6
17.1
16.5
16.2
18.4
14.5
13-3
4.8
4.5
4.9
3.*
2.3
1.6
Regenerator
CaO
Wt %
75.9
75.4
72.8
79.5
-
75.5
87.2
72.8
- .
-
-
-
96.3
-
SiO-
wt %
16.3
16.4
18.8
17-9
-
17.0
9.2
15.6
-
-
-
-
1.9
-
Boiler
CaO
Wt*
47.7
66.4
69.6
67.8
66.0
69.6
71.0
70.2
-
-
-
-
96.1
-
Sio
wtg
11.2
15.5
17.6
17.7
18.2
19.4
13-9
16.3
-"
-
-
-
1.3
-
Stack
Cyclone
CaO
Wt*
74.6
63.5
60.8
59.5
63.2
64.8
63.8
64.7
-
80.8
86.8
78.8
89.6.
-
S10p
Wt %
21.1
16.6
18.3
18.8
19.8
••20.2
19-3
19-5
-
1.2
0.6
0.8
0.5
-
ELutriator
Fines
CaO
Wt *
63.8
64.3
63.5
-
62.5
63.2
67.6
66.3
82.5
85.0
-
-
94.4
-
SiO
wtg
22.4
19.4
20.2
-
20.8
20.8
17.4
18.1
1.0
0.8
-
-
0.8
-
ELutriator
Coarse
CaO
Wt*
-
61.1
70.1
68.4
66.0
74.2
72.6
71.2
-
-
-
-
95.0
-
SiOp
wt *
_
20.6
18.5
18.6
20.1
19.0
16.2
15.9
-
-
-
-
1.0
-
Regenerator
Cyclone
CaO1
Wt *
62.7
61.3
64.3
65.8
-
65.1
65.6
66.7
84.7
-
-
-
87.2
—
310
Wt|
19-1
18.4
18.2
18.8
-
19.8
17. *
18.2
0.8
-
-
-
0.5
—
to
to
-------
APPENDIX B - TABLE XII
Sieve Analyses of Gasifier Bed Run 5
Sample No
-Qaslfier
Bed
51225
51255
51236
51245
50001
50029
5004?
50048
50055
50061
50075
50114
50125
50155
50149
+2800
* ^
wt.g
2.55
0,44
1.57
1.56
1.70
5.55
0.28
0.22
0.68
0.24
0.72
0.66
0.64
0.65
0.95
2800
l4oo
u
wt.#
6.55
41.28
45.21
^§.92
48.02
49.17
54.27
28.40
41.91
58.59
41.17
42.90
44.16
47-79
44.62
1400
1180
n
Wt.#
22.15
15.02
15.07
15.27
15.55
15.07
11.89
12.12
11.78
12.86
11.69
15.20
15.25
14.11
1$.24
1880
850
i*
wt.#
55.55
19.87
20.55
20.41
19^60
17.65
18.88
20.99
I8.;o8
18.20
18.58
19.64
19.87
18.95
19.94
850
600
M>
Wt.Jg
22.87
14.15
10.96
12.95
11.65
10.17
15.66
16.95
12.74
13-59
15.96
12.87
15.56
12.21
15.29
600
250
Ifc
wt.#
12.61
11.04
6.85
6.11
5.68
6.22
19.02
21.52
14.66
16.28
14.08
10.40
8.52
6.52
6.96.
250
150
U
Wt.#
0
OC22
0
0
0
0.21
0
0
0.14
0.24
0
o;i7
0
0
0
150-
lOOy
Wt.#
0
0
0
0
0
0
0
0
0
0
0
0.17
0
0
0
Less
Than
100 U
0
0
0
0
0
0
0
0
0
0
0
0
0
0
0
Total
%
100
100
100
100
100
100
100
100
100
100
100
100
100
100
100
Day/Hr.
5.1045
•
6.0730
12.1600,
12.1800
13.0400
17.1800
18.1100
21.1600
21.1800
22.0750
22.1745
25.0530
25.1400
26.0400
26.1000
10
00
-------
APPENDIX B - TABLE XIII
Sieve Analyses of .Regenerator Bed (Run
Sample No
Regen Bed
Run 5
51197/73
51198/73
51232/73
51239/73
50008/73
50124/73
50025/73
50036/73
50044/73
50051/73
50059/73
50071/73
50012/73
50131/73
50150/73
+2800
U
wt.$
0.64
0.33
1.15
0.64
2.14
0.46
1.44
09.43
0,44
0.21
0.43
0.36
0.31
0.57
0.71*-
2800
1400
Wt.$
39-30
31.46
41.67
47.92
^5.99
40.23
38.46
17.93
3^.37
27.66
32.83
28.83
35.64
40.92
41.98
1400
Il8o
wt.#
10.22
8.94
12.93
13.^2
11.23
13-79
10.58
7.3^
9.31
10.64
11.59
10.85
12.75
13.58
13.09
Il8o
850
Wt.#
18.53
20.2
22.41
18.85
18.72
20.23
16.83
17.06
22.62
17.98
18.67
18.74
20.28
30.84
19.26
850
600
Wt.#
16.29
18.54
14.66
12.14
13.36
14.25
• 12.50
18.79
20.40
16.49
15..^5
16.9^
15.67
14.15
16.79
600
250
Wt.#
15.02
20.53
7.18
7*03
8.56
10.80
20.19
27.65
12.42 '
25.85
20.82
24.14
14.90
9.75
7.9
250
150
Wt.$
0
0
0
0
0
0.23
0
2.16
0.44
1.06
0.21
0.18
0.15
0.19
0.25
150
100
wt.^
0
0
0
0
0
0
0
1.73
0
0.11
0
0
0.15
0
0
-100
»
wt.#
0
0
0
0
0
0
0
6.91
0
0
0
0
0.15
0
0
Total
wt.#
100
100
100
100
100
100
100
100
100
100
100
100
100
100
100
Day/Hr.
2.1730
% 2. 1930
6.0730-
12.1600
13.0600
15.1400
17.1130
17.1800
21.0700
21.1800
22.0730
22.1745
25.0530
26.0400
26.1000
I
10
to
VD
I
-------
APPENDIX B - TABLE XIV
Composition of CAFE Solids Run 5 (Ignition at 900°C)
Sampling Position:
Time
Day, Hour
5.1530
5.2200
5.1045
6.0750
12.1600
12.1800
15.0400
15.0600
17.1150
17.1800
21.0700
21.1800
22.0715
22.1745
25.0550
25.1400
26.0400
26.1000
Boiler
Loss
Wt %
1.05
-
0.24
0.10
-
-
-
1.18
-
-
-
-
-
-
-
-
-
Gain
Wt %
5.59
-
0.47
-
-
0.47
1.40
1.90
-
5-07
2.55
1.68
1.64
0.75
1.52
2.51
1.49
2.18
Stack
Cyclone
Loss
Wt %
7.91
20.46
15.62
5.56
4.77
7.20
5-91
1.75
2.22
2.89
5.52
4.12
5-19
5.57
5.50
5.46
5.24
4.95
Gain
Wt %
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
ELutriator
Coarse
Loss
Wt %
0
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
Gain
Wt %
0
.5.55
-
5.67
6.78
5.97
6.55
5.54
6.52
5.97
7.22
5.15
8.00
7.97
10.82
8.59
8.79
7.78
Elutriator
Pines
Loss
Wt %
11.54
21.2
-
-
-
-
-
-
-
-
0.59
0.88
-
-
-
-
-
-
Gain
Wt %
-
4.69
5.45
4.14
-
5.90
2.82
7.27
6.10
-
-
5.70
5.50
6.11
6.72
4.47
5.14
Regenerator
Cyclone
Loss
Wt %
-
-
-
-
-
-
_
-
-
_
_
-
-
-
-
-
-
Gain
Wt %
0.80
0.86
1.24
1.15
1.65
1.07
1.46
1.18
1.87
1.55
2.26
1.55
1.46
1.52
1.53
1.40
1.44
M
o
I
-------
APPENDIX B - TABLE XV
SOLIDS REMOVED DURING RUN 5* KG. (RAW DATA)
DAY.HOUR GAS'R
2.
2.
2.
2.
2.
2.
2.
2.
• 2220
• 2335
• 0130
.0330
.0530
.0730
.0930
• 1230
• 1 400
• 1600
• 2100
• 2200
• 2230
.2330
• 0030
• 0130
• 0230
• 0330
.0430
• 0530
• 0630
0730
2.0830
2.0930
2.1230
2.1630
2.1730
2.1830
2.1930
2.2030
• 2130
• 2330
• 0230
.0330
.0730
3. 1130
3.1430
3.1630
3.1730
3.1830
2
2
3
3
3
REGEN REGEN ELUTR BOILER BOILER ELUTR
CYCLONE FINES BACK FLUE COARSE
4.31
-
0.91
0.45
0.45
0.45
0.45
0.45
0.45
1.13
3-40
4.99
-
1 .81
3.86
-
3.63
7.71
1.13
0.34
0.34
1.59
0.91
0.91
1 .70
2.61
1 .81
I .59
1.59
0.57
12.70
0.23
2.49 0.34
-
0.68
0.45
0.68
14.51
14.51
1 1 .79
6.94
1 . 59
3. 18
1 . 59
1 .47
1.13
0.91
1 .02
4.54
-
7.26
0.34 1.36
1.13
0.45
-.
3.86
0.45
0.23
9.98
_
5.44
-
3.63
1.36
2.72
5.22
-
-
«
3.29 - 5.22
-
1.13 - 2.04
-
2.72 0. 4.76
3«63 0.34 7.26
2-83 1.81 5.62
3.63 1.81 5.90
...
...
-
28.58
- 231 -
-------
SOLIDS REMOVED DURING RUN 5* KG. (RAW DATA)
DAY.HOUR GAS'R REGEN REGEN ELUTR BOILER BOILER ELUTR
CYCLONE FINES BACK FLUE COARSE
3.1930
3.2330
4.0330
4. 1030
4. 1230
4. 1330
4. 1430
4. 1530
4. 1630
4. 1730
4. 1830
4. 1930
4.2130
4.2230
4-2330
5.0030
5.0130
5.0330
5.0430
5.0530
5.0730
5.0830
5.0930
5. 1030
5* 1050
5. 11 30
5.1230
5.1530
5.2200
6*0030
7.0430
8*0100
8.0715
8.2030
8.2130
9.0030
9.0430
9.0530
9.0700
10* 1930
13*38
-
67.70
-
14.74
14.97
-
13.61
21.77
1 1 -34
1 1 «34
10.89
12.02
1 2 . 70
13.88
15.20
14.83
16.33
-
13.15
14.29
13.83
12.70
1 1 .34
10.43
9.07
10.43
-
-
-
11.79
-
-
-
-
-
-
-
-
-
0.9 1
0.57
-
2.27
-
-
1.36
-
-
-
1 -36
-
-
-
-
1 .81
-
-
1 .19
-
0.95
-
0.91
-
-
-
-
1 .36
-
-
0.79
0.45
0.23
-
-
-
-
-
0-23
-
3.18 3.63
4.08 0.11
-
10.21 0.45
-
-
6.58 0.23
-
-
• -
6.80 0.23
-
- .
-
— .
9.07 0.23
-
-
7.31 0.23
— _
6.40 0.23
— _
5.44
.
_ _
«. w
_ _
12*70 0.45
0.91
7.48
.
4*31
-
0*68 0.11
-
-51.82
28.80
6.58
1 1 .85
5.44
2.61
_
16.78
_
w
9.07
-
.
_
2.04
M
»
_
•»
15.31
—
12.38
7-76
8.62
_
.
_
1 7.24
—
_
_
_
6.58
5.22
6*35
1 .93
-
4.10
- 232 -
-------
SOLIDS REMOVED DURING RUN 5* KG. (RAW DATA>
DAY.HOUR GAS'R REGEN REGEN ELUTR BOILER BOILER ELUTR
CYCLONE FINES BACK FLUE COARSE
1 1 .0930
1 1 .2230
12.0030
12.0130
12.0930
12. 030
12. 230
12. 330
12. 430
12. 530
12. 630
12.2230
12.2330
13.0030
13.0130
13*0400
13*0600
13.1230
13.1700
14*0630
14* 1 100
14.1630
14.1900
15.0330
15.0730
15.1230
15* 1730
16*0005
16.0800
1 6 . 1 1 40
16.1230
16.1900
16.2230
17.0010
17.0215
17.0530
17*0830
17.1 130
17.1830
17.1930
1.13
1 . 59
12.70
3.18
...
1 .47
-
-
66.90
1.36
12.47
7.94 0.68
0.91
0.45
1.36
-
2.27
...
1.36
0.45
0.91
.
...
...
4*99
0.91
27.22
27.22 0.91
0.91
1.81
...
1.47
0.91
1.02
...
1.36
19.96
4.31
-
3*06
-
-
-
3. 18
-
-
0*68
0*45
2.27
-
2.38
-
-
0.45
0.45
-
-
-
0.23
0.45
-
0.68
2.72
2.04
-
2.83
1 .70
1 .02
-
1 .02
-
0.68
2.38
-
2.61
-
-53.98
-
4.08
-
2*49
0.91
1.81
2.49
2*61
3*63
4.31
2.04
-
7.26
•*
-
0.45
0.1 1
0.1 1
-
3.63
0.45
0.79
-
2.83
3.29
5.10
-
8.16
-
7.31
18.14
50. 12
1 .47
7.26
-
-
-
-
10.89
-
8.85
5.67
5*44
19.96
18.48
27.22
6.58
7.26
-
13.61
9.98
10.43
11 .79
3.29
20.07
-
10.89
18*14
13*61
-
16*10
15.03
13.61
11 .79
19.96
-
-
-
-
13.61
5.53
-
-
-
-
-
-
-
-
-
-
-
6.45
-
-
-
-
-
-
-
-
-
-
17.24
-
-
-
-
-
-
- 233 -
-------
SOLIDS REMOVED DURING RUN 5* KG. (RAW DATA)
DAY.HOUR GAS'R REGEN REGEN ELUTR BOILER BOILER ELUTR
CYCLONE FINES BACK FLUE COARSE
17.2100
18.0100
18.0430
18.0840
18.1 130
18.1530
18.21 15
18.2345
19*0100
19.0815
19.1330
19.2030
20.0200
20.0500
20.0715
20.1400
20.1515
20.1730
20.1910
20.2030
20.2130
20.2330
21 .0030
21 .0230
21 .0430
21 .0530
21 .0730
21 .0930
21 .1 130
21.1155
21.1430
21 .1530
21.1600
21.1630
21.1930
21 .2000
21.2230
21.2300
22.0400
22*0700
1.42
97.98 22.00
0.45
_
0.23
_
. - -
-
.
.
...
.
0.23
0.11
0.11
_
0.45
0.09
0 . 28
_
0.91
1.36
...
2.04
...
1.81
0.68
1.36
.
12.47
2.27
...
10.21
0.68
11 . 79
11.34
-
2.72
2.72
...
7.17
21.32
-
-
0.91
0.23
-
-
32.21
1.13
-
0.1 1
-
0.45
-
-
0.23
0.1 1
0.23
-
1.36
0.45
-
0.68
-
-
0.45
0.23
1 .02
-
0.45
-
-
1*36
-
-
-
1 .81
2.27
-
7.60
-
2.72
-
3.18
I .81
1.13
-
-
2.04
5.67
2.27
5.78
3«86
3-29
180.53
0.45
0.06
0.23
-
•
-
-
-
-
-
0.23
1.13
-
-
2.72
-
-
-
-
-
3. 18
-
4.08
-
14.63
-
6.71
-
4.54
6.35
-
1.59
-
0.68
-
3. 18
22.23
7.03
8.98
76.20
8.16
1.81
16.33
9.53
8.85
13-72
6.58
1 1.57
13.38
10.66
8. 16
1 1.57
13.15
-
5.44
10.32
-
.
-
-
-
18.60
14.97
12.70
-
-
-
12. 16
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
-
5.44
4.54
-
-
-
-
-
.
-
19.05
•
.
M
-
-
-
-
-
- 234 -
-------
SOLIDS REMOVED DURING RUN 5* KG. (RAW DATA)
DAY.HOUR
22.0945
22.1030
22.1130
22.1730
>0300
.0730
.0800
.1730
.1930
.2230
.0130
.0430
.0730
.0930
1130
1230
1330
24.1530
24.1730
24.1930
2030
2130
.2230
.2330
>0030
.0130
• 0230
.0330
.0430
.0530
.0630
.0730
.0830
.0930
• 1 130
> 1230
• 1330
25.1430
25.1530
25.1730
GAS'R REGEN REGEN ELUTR
CYCLONE FINES
BOILER BOILER ELUTR
BACK FLUE COARSE
4.99
23.
23-
23.
23-
23.
23.
24.
24
24.1
24.i
24.
24.
24.
24.
24.
24.
24.
25.
25.1
25.i
25.
25.
25.
25.
25.i
25-
25.
25.
25.
25.
-
2.04
2.49
-
1.13
0.68
-
3.40
3.86
2.83
2.04
2.38
-
2.27
-
1 .47
1 .36
-
1-59
-
1 .81
-
1.36
-
1 .36
-
1.36
-
1.13
-
1*13
0.91
-
2.04
-
-
1.02
-
1 • 13
-
1.36
—
0.79
-
3*40
5.35
2.04
5*90
4.08
4.42
-
4.99
-
4*65
4.76
-
5.22
-
4.54
-
4*54
-
4.54
-
4.54
-
4*08
-
4*08
2.49
-
5.90
-
-
3.63
-
-
5.44
4.54
-
1 .81
1.02
-
3«18
4*54
3.29
4.76
3*86
-
7.26
-
4.76
5.90
4.08
-
-
7.03
-
-
5.90
-
4*54
-
4.99
4»
4.99
-
2.27
-
4.76
-
-
4.88
0.45
-
13.78
16.10
43. 54
11. 79
11.11
-
1 7.46
14.29
18.14
14.42
28.58
12.59
-
11.11
13.83
10.43
12.59
-
10.89
-
10.43
-
1 1.79
-
9.53
-
10.89
-
9.53
-
12.47
12-70
2.49
10.43
2.04
7.71
6-35
3.18
2.49
19.50!
19.96
- 235 -
-------
SOLIDS REMOVED DURING RUN 5» KG. (RAW DATA)
DAY.HOUR GAS'R REGEN REGEN ELUTR BOILER BOILER ELUTR
CYCLONE FINES BACK FLUE COARSE
25.1830 - - 1.59 5.56 5.90 - 11.43
25.2130 .... 7.26 6.35
25.2230 - - 1.8! 6.35 -
25.2330 - - - 5.90 $.35
26.0030 - - 1.13 3.18
26.0130 - 4-08 7.26
26.0230 - - 1.13 2.95 -
26.0330 - 4.54 10.89
26.0430 - - 0.91 2.72 ...
26*0530 .... 3.|8 6.gg
26.0630 - - 0.91 2.72 ...
26.0730 .... 4.0g 9.07
26.0830 - - 0.91 2.72 ...
26.0930 - - 0.68 2.72 2-04 10.43
26.1230 - - 1.81 2.49 5.22 9.98
26.1530 - - 2.04 3.63 5.67 11.57
26.1800 - - 1.59 3-40 4.99 17.01
26.1830 - - 1.13 1.81 - 5.81
- 236 -
-------
NJ
to
I 1 1
SULPHUR REMOVAL EFFICIENCY
LIME REPLACEMENT RATIO
DENBIGHSHIRE STONE
BCR 1691 STONE
GASIFIER DEPTH
GASIFIER TEMPERATURE
Z-I2OO
2400 3-I2OO 2400 4-1200 2400 5-1200
RUN DAY-TIME
2400 6-I20O
FIG.815. SHEET I
-------
to
to
oo
too
90
80
m 60
50
£
IftJ (A 9
u •
2
e
0 I
0
o 25
*
g S 20
z*
g t 15
C o
w o 900
800
BCR 1691 STONE-»
I
I I I
SULPHUR REMOVAL EFFICIENCY
LIME REPLACEMENT RATIO
BCR 1691 STONE
GASIFIER DEPTH
GASIFIER TEMPERATURE
I
I
I
BCR 1691 STONE
I
I
I
8-2400 9-1200
II-24OO I2-I2OO 2400
RUN DAY -TIME
16-1200 2400 17-1200
FIG BI5. SHEET 2
-------
U)
vo
SULPHUR REMOVAL EFFICIENCY
LIME REPLACEMENT RATIO
GASIFIER TEMPERATURE
800
2400 21-1200 2400 22-1200 24OO 24-1200
RUN DAY-TIME
2400 25-1200
2400 26-1200
FIG. BIS. SHEET.3.
-------
10
6
i
O
<
<9
10
o 8
| e
8 2
100
at
>•*
t 50
§
CO
5
CO
N.
E
0
6
5
4
3
8
o IIOO
£ 1050
K IOOO
> -TV
I I I I
REGENERATOR GAS SOz CONCENTRATION
RE6ENERATOO SELECTIVITY CoS TO CoO
RECENERATOR SUPERFICIAL GAS VELOCITY
REGENERATOR TEMPERATURE
I
I
I
Z-IZOO 24OO 3-I2OO 24OO 4-I2OO
RUN DAY-TIME
2400 5-1200 2400 6H200
F16. B16. SHEET. I
-------
M
u t-
10
8
6
4
Z
too
li
50
gfc
^ 6
u_
t' *
li 4
5 OT 3
£ o
So 1100
2 IO5O
UJ
*~ 1000
8-240O 9-1200
I I I ~
REGENERATOR GAS SOj CONCENTRATION
REGENERATOR SELECTIVITY. CoSTOCoO
REGENERATOR SUPERFICIAL CAS VELOCITY
REGENERATOR TEMPERATURE
1-2400 12-1200 240O
RUN DAY-TIME
I6-I2OO 24OO 17-1200
FIG. B16.SHEET.2
-------
0-5
M >
»I
5 <
s „
aS
10
8
6
4
2
100
si s°
: , o
£ £ 6
1 t 5
11 4
I I 3
g .o MOO
I 1050
u
IOOO
RgCEHERATOR CAS SO2 CONCENTRATION
I, W\//S-AS/^^
REGENERATOR SELECTIVITY CoS TO CoO
REGENERATOR SUPERFICIAL GAS VELOCITY
REGENERATOR TEMPERATURE
I
I
I
I
I
24OO
2I-I2OO 24OO 22-I2OO
23-24OO 24-I2OO 24OO
RUN DAY-TIME
25-1200 240O 26-1200
FIGJlfi SHEET 3
-------
APPENDIX C
RUN 6
Operational Leg, Inspection, and Data
Page
Operational Log 244
Inspection, Figures 1-14 257
Data Table I Temperatures and Feed rates 268
II Gas flow rates 280
III Pressures . 292
IV Desuij^hurisation Performance 3O4
V Gas Compositions 316
VI Sulphur and Stone Cumulative 33O
Balance
VII Analysis of Solids, Total 344
Sulphur
VIII Analysis of Solids, Sulphate 345
Sulphur
IX Analysis of Solids, Total 346
Carbon
X Solids removed 347
XI Sieve analysis - Stone feed 353
XII " " » Gasifier Bed 354
XIII " " - Regenerator 355
Bed
XIV " " - Elutriator 356
Coarse
Figure 15 - Chronological plot of unit performance 357
- 243 -
-------
APPENDIX C
CAFB RUN 6
OPERATIONAL LOG
3.6.73 to 5.6.73 (Unit warm up)
The scheduled start up was delayed a few hours due to
difficulty in starting the gas burner which was traced to
deposits in the gas pilot venturi which was stripped out,
cleaned and replaced. Warm up started at 07.OO and continued
uneventfully at 12"C per hour until a gas space temperature
of 500°C was reached when after a brief holding period the
rate was increased to 2O°C per hour. Kerosene was added at
11.00 on 5.6.73 to bring the temperature near the target of
85O*C and the joint around the gasifier lid was sealed with
fireclay and asbestos. At 16.30 the stone feed was started
using material retained from the end of Run 5 and apart from
some gas pilot flame outs the feeding continued steadily. At
2O.45 BCR 1359 limestone feed was started and the bed depth
continued to rise slowly with a feed rate of 62 kgs/h
(135 Ibs/h).
6,6.73 (Day X of Gasification)
The regenerator was well fluidised and bed transfer was good
but the gasifier bed temperatures were spread by 25°C and
showed some general instability possibly due to erratic fuel
input. The gasifier lid seal was leaking in some areas and
was repacked with fireclay and asbestos rope. The automatic
valve for controlling the fines return into the gasifier was
not operating and the pressure tapping which controls this
operation was found to be blocked with fine material.
At 13.30 the boiler door was shut, the test probe inserted
and combusting conditions resumed to check out bed transfer
and other features prior to gasification. Some problems were
found with the flame detector sensors but apart from an inter-
mittent fault in the pilot flame failure repeater light all
the systems were working.
Gasification started at 21.1O and almost immediately the
persistant lid leakage stopped due to the carbon deposition.
The new boiler gas sampling system was installed using a
small cyclone on the rear end of the boiler and sampling the
gas from the stream through the cyclone. Initial S02 levels
- 244 -
-------
in the boiler were approximately 24O ppm with a regenerator
S02 output of 8% at 1O45°C.
7.6.73 (Day 2)
There were some problems with the main flame and pilot flame
failure warnings which persisted even though botn flames were
well established. The unit ran very steadily with consistent
boiler and regenerator SO2 levels. A system of air injection
into each leg of the bifurcated duct had been installed so
that differences in gas flow in each duct might be measured
by the differences in the temperature rise with a given air-
injection rate. Initial trials were made on the left hand
duct and although sharp temperature increases of 10°C were
observed with 18 m3/h (1O.6 ft3/m) of air injection the
results were not repeatable and it was apparent that the gas
burnt in an irregular manner because one thermocouple further
downstream registered a 6O°C temperature rise for the same
flow rate of air.
Bed transfer between the gasifier and regenerator was very
good and it was necessary to reduce the bleed rate and pulse
rate of the nitrogen injections to very low levels to main-
tain regenerator temperature. At 2O.OO samples were taken
of the bed material and dust from the various collection
points.
8.6.73 (Day 3)
Some adjustments were made to the regenerator air rate to
provide a O.2% oxygen level in the off gas stream after
samples of bed and dust material was collected at O1.30. It
was not possible to maintain the trace oxygen level in the
regenerator off gas even with high air rates suggesting
excessive carbon on the stone which was burning off in the
regenerator. The gasifier temperature was raised to 9OO°C
in an attempt to burn off more of the carbon.
A further set of samples was taken at 13.OO before tests
were made on the regenerator off gas flow rate by helium
injection into the regenerator upper gas space and measurement
of the downstream concentration.
The pump on the boiler water pressurisation system developed
a problem at 19.3O and was unable to maintain the pressure
in the system without the standby pump. The pump could not
be examined without a total shut down and an emergency hand
operated pump was connected up to provide additional back up
facilities.
- 245 -
-------
9.6.73 (Day 4)
Bed material and dust samples were collected at 02.00 before
cutting off the bed feed to lower the bed height. Soon after
this the scrubber knock out vessel blocked and water was
drawn through the recycle blower before the supply could be
turned off. When the system was cleared and restarted the
gasifier distributor pressure drop had risen from 4 kPa
(16 ins w.g) to 5.5 kPa (22 ins w.g) with the same total
gas flow. Debris from the obstructed flue gas recycle line
must have been carried through to the distributor nozzles.
At 06.30 some problems were encountered with the oil preheater
which repeatedly cut out on overtemperature so reducing the
oil temperature and upsetting the oil input to the gasifier.
During this period without bed feed the loss in bed height
was small but there was a steady decline in gasifier perform-
ance.
The regenerator off gas oxygen level had gradually risen to
O.5% and the gasifier temperature was lowered to 880°C which
was reckoned to be a more efficient" operating temperature but
within the following few hours there was no observable
improvement in S02 removal efficiency and the temperature
increased to 910°C. At 14.OO further bed and dust samples
were collected before the resumption of stone feed at a
molar rate. It was observed that there was some slight smoke
from the stack which disappeared when the flue oxygen was
increased from 1.5 to 2.0%.
10.6.73 (Day 5)
The unit continued to run steadily with stoichiometric stone
feed and efficiencies between 85% and 9O% were measured. A
problem arose with the liquid nitrogen supply due to a fault
on the road tanker which prevented the refilling of the supply
and the tanker did not return later in the day as arranged.
This situation resulted in a critical period during which
the nigrogen supply was obtained from compressed gas cylinders
until the liquid supply tank was replenished. Some bed mater-
ial and dust samples were taken at 10.30 in case the unit was
shut down because of the nitrogen shortage. During this
period further problems were encountered with the oil heater
which continued to shut down at intervals due to the over
temperature switch operation.
- 246 -
-------
At 18.OO bed material and dust samples were collected and
after this the sampling cyclone on the boiler door was
removed so that the line could be rodded out. It was
heavily obstructed with lime deposits in the boiler door.
After this operation the boiler SC>2 level apparently rose
from approximately 175 ppm to 35O ppm. Bed material and
dust samples were collected at 23.59.
11.6.73 (Day 6)
The boiler sample line was rodded at regular intervals to
remove any lime deposits and the SC>2 concentration in the
boiler usually increased marginally after this operation
indicating that absorbtion could take place in the sample
tube. During this period the scheduled stone feed of 2O
kgs/h (44 Ibs/h) was difficult to hold steady and when a
fresh bag of stone was added the variations were most
marked possibly due to varying stone particle distribution.
At 10.2O the air cooling supply to the boiler probe failed
and the standby compressor was switched in but in the inter-
val the temperature of the probe rose considerably above the
control point of 6OOaC. The regenerator lower bed tapping
blocked but it was successfully cleared by rodding. Soon
after this the regenerator temperature started to drop below
the set point too fast for the controller to hold and the
situation was controlled by switching off the transfer pulse
system to prevent the flow of bed material and gradually the
temperature recovered to its operating level. The boiler
flue gas was sampled at 13.30 to determine the solids content.
During the afternoon there were several instances of the
regenerator temperature dropping due to high flow rates
in the transfer line but after some adjustments the system
recovered. Bed material, dust and product gas samples were
taken at 19.OO.
Various mechanical problems arose towards the end of the day
due to blocked pressure tappings and seized valves but all
these were overcome without difficulty. The butterfly valve
in the left hand cyclone drain leg began to stick and it was
discovered that the pneumatic valve operator was leaking
around its seal so reducing the operating torque. The joints
were tightened but still manual assistance was required at
intervals to assist valve operation. Further problems with
low regenerator temperatures and adequate bed transfer could
be overcome by shutting off the pulse system and using the
slow steady bleed of nitrogen to operate the material transfer,
- 247 -
-------
12.6.73 (Day 7)
It appeared that some change had occurred in the fines
return system because the material collection rate at the
boiler and stack drain points increased significantly and
the regenerator fines collection rate fell. Soon after
this period the regenerator cyclone accumulated an abnorm-
ally large quantity of material at a rate of 5.2 kgs/h
(11.5 Ibs/h) and there may have been a hold up in the fines
returning to the regenerator which cleared releasing a large
quantity of material. During this period of operation the
regenerator air rate had been reduced thus requiring a lower
circulation rate to maintain the control temperature. This
low rate was near the minimum rate obtainable by using the
bleed gas only without nitrogen pulses for trimming control.
A sieve analysis on the bed feedstock at 03.OO showed one
batch was very dusty with only 9.2% of the material greater
than 14OO microns. The erratic fines collection rate may
have arisen from the feedstock variation. At 08.OO bed
material and dust samples were collected with the unit run-
ning at a steady level.
The stone feed rate was reduced to about % stoichmetric
about 11.30 but further stone size variation made accurate
metering difficult. Following this, the regenerator air
rate was increased to achieve maximum S02 removal rate. This
caused a regenerator high temperature condition due to the
increased air rate liberating more heat and whilst the auto-
matic controller demanded more bed flow for coolant the
system was hampered by the rate of transfer from the regener-
ator which is manually controlled. During this period the
gasifier drain was inadvertantly left open after bed material
was drained off to lower the gasifier bed level by 12.5 mm
(.5 ins).
The regenerator air rate had been gradually increased until
a value of 3O m^/h (17.6 ft^/m) showed a maximum SO2 removal
rate under these conditions of unit operation. After six
hours of good operation bed/ gas and dust samples were collected
at 20.00. After repeated malfunction of the oil preheater it
was discovered that the electrical relay for the heat circul-
ating pump was sticking and by selecting a manual override
control the intermittent functioning was overcome and the
circulating pump operated correctly. Samples were collected
of bed material, dust and the gas product at 23.59.
- 248 -
-------
13.6.73 (Day 8)
The continuous operation of the circulating pump increased
the oil feed to the gasifier and this increase in fuel rate
caused an increase in the gasifier space pressure but after
reducing the fuel back to the correct value some increase in
pressure still remained. Preparations were made to start
shooting gasifier bed material into the left hand cyclone
to remove some of the deposits in the entry which were prob-
ably causing the increased pressure drop. During this period
the left hand cyclone stopped working and significant quan-
tities of material were carried over into the boiler so low-
ering the gasifier bed height. The cyclone drain system was
restarted and began working reasonably well until the butter-
fly valve actuator malfunctioned again requiring manual assist-
ance at almost every operation to complete its cycle. The
compressor for the boiler probe cooling air failed during the
night with the result that the probe temperature rapidly
rose above 10OO°C before the standby compressor could be
brought in.
At O5.00 some experiments were made by inducing different
velocities in two sections of the gasifier bed promoting a
gross circulation or gulf streaming in the bed. This was
achieved by controlling the air flows to the split plenum
of the distributor.
At 08.00 samples were taken of the bed material, dust and
product gas. The cyclone fines return system continued to
give trouble and a new actuator was obtained and fitted
together with a water spray to keep the actuator mechanism
cool. The stack top washer support legs buckled due to
corrosion and a temporary repair was made. At 16.00 bed
material and dust samples were collected.
14.6.73 (Day 9)
The unit continued to run steadily with some small problems
with the regenerator bottom tapping and scrubber which was
rectified. At 04.OO samples of bed material and dust were
collected. A gas analysis was made on the regenerator off gas
using gas chromotography with an average S02 concentration
of 6.8% compared to 7.2% with the Maihak analyser. Some
problems arose during the early morning with the cyclone
drain system which stopped functioning because the butterfly
valve was not sealing properly. During this period the
shooter overfilled the cyclone and a large quantity of material
was transported into the boiler and through to the scrubber
- 249 -
-------
blocking up the water drain and so flooding the recycle and
gasifier blowers. At this period the gasifier gas space
pressure was rising fairly rapidly towards the recommended
maximum level and further trials were started to shoot
material at both cyclone inlets in turn in an attempt to
prolong the operational period before a burn out.
At 15.30 samples were collected of bed material and dust.
The controlling air valve on the probe cooling system failed
and went to a fully open position which overcooled the probe.
At 21.30 the shooter was stopped to the right hand cyclone
because the gasifier space pressure rise was not improved by
its use. Soon afterwards there were high material losses
through to the boiler probably caused by a gas flow up the
right hand cyclone drain leg which was unable to sustain a
sufficiently deep seal of fine material necessary to balance
the high pressure drop across the cyclone entry. At this
stage further unit operation was not very useful and sulph-
ation and burn out was started at 22.45.
15.6.73 (Day 10)
The carbon burn out was prolonged and after six hours kerosene
combustion was established although there was still some
residual carbon in the ducts which then burnt off. The unit
was shut down at 11.OO to clean the rear end of the boiler
and restarted to recover the temperature before shutting
down again to clean the boiler front soot box. Gasification
was restarted at 19.55 without difficulty.
16.6.73 (Day 11)
The bed circulation system was erratic in the early part of
the day and there was an apparent link between irregularities
in the boiler S02 level and the operation of the gasifier to
regenerator transfer pulse system. It was possible that there
was a back flow of gas up the internal cyclone drain line so
disturbing the cyclone performance. The remainder of this
day was spent in settling the bed transfer system and regener-
ator performance both of which were rather erratic. The
regenerator lower pressure tapping blocked repeatedly and
proved an unreliable guide to bed height.
17.6.73 (Day 12)
The stone feed rate of 27 kgs/h (59.5 Ibs/h) was maintained
but was erratic probably due to inconsistent limestone feed-
stock size distribution. At O5.OO bed and dust samples were
- 250 -
-------
collected to determine the performance of the unit with the
2 X stoichmetric feed rate of limestone. During this
period the regenerator performance was not as good as usual
although the gasifier efficiency was high. During the early
morning the fines recovered from the regenerator were aver-
aging 6 kgs/h (13.2 Ibs/h) over a typical 3 hour period and
later in the afternoon this increased to 13.6 kgs/h (30 Ibs/h)
over a 5 hour period.
At 15.3O samples were collected of the bed material and dust
from the various collection points. The hot stone shooting
system was set to operate on the right hand cyclone which
drains into the gasifier to regenerator transfer line.
During some periods when the shooter operated frequently,
the regenerator temperature dropped markedly and the auto-
matic controller found difficulty in accomodating these slugs
of colder stone which drained from the cyclone.
18.6.73 (Day 13)
The regenerator performance improved during the first few
hours of this day in spite of a slight drop in the gasifier
bed height. Stone and dust samples were collected at Ol.OO
before changing the stone feed rate to l*j stoichmetric
addition rate. The regenerator temperature control became
erratic after the hot stone shooter operating rate was slowed
down and this has been due to the colder stone which results
from a slower operating rate.
Three gas samples were taken from the boiler flue at 16.30
and analysed for NOx giving 130, 146 and 152 ppm, bed
material and dust samples were taken at 17.OO.
At 18.08 the left hand fuel injector was shut off and its oil
supply routed to the single nozzle positioned through the
distributor. At 19.12 the centre injector fuel supply was
added into this single nozzle and at 20.O6 the third fuel
injector was included to provide all fuel entry through this
single nozzle positioned in the distributor. The boiler SO2
level increased very sharply after the total oil supply was
fed to the bottom injector giving efficiencies of 51% minimum
and at the same time there was an increase in the fines
drained from the left hand cyclone suggesting a bigger
material carry over due to the single injection fuel supply
condition.
- 251 -
-------
19.6.73 (Day 14)
The air supplied with the fuel was changed from 11.9 m3/h
(7 ftvm) to 17 ra3/h (10 ft3/m) to, determine the effect of
this air rate but the boiler S02 level remained high at 60O
ppm. A set of samples was collected at 05.00 followed by
trials with the single fuel injector performance at gasifier
temperatures of 9OO°C, 87O°C and 84O"C. Boiler SO2 levels
were higher at 9OO°C than at the two lower temperatures,
both of which gave similar values around 66% sulphur removal
efficiency and the unit was then returned to 870°C gasifier
temperature. The regenerator off gas was analysed by gas
chromatography showing 1.3% C02 and 7.1% S02 with the bal-
ance being nitrogen with a trace of water. This SO2 con-
centration was higher than 6% average value obtained by
the Maihak analyser which was the instrument used for
continuous analysis.
At 21.OO some problems were encountered in maintaining good
bed circulation between the gasifier and regenerator. The
automatic controller was unable to control correctly and the
system was switched to manual control with a high pulse rate
consuming 4 times the normal nitrogen demand.
20.6.73 (Day 15)
Further trials were made with gasifier bed gulf streaming to
determine if this would improve the fuel distribution from
the single injector which at this point could have been the
source of continuing poor bed transfer. Trials were made
with 30% velocity differentials but there was not any marked
effect upon transfer rate or boiler SO2 level. The latter
was masked by the irregularity in the left hand cyclone drain
butterfly valve closure which permitted nitrogen to leak up
the drain leg and blow fines into the boiler.
At 03.10 the fuel supply was returned to the three side
injectors and by 05.3O bed transfer improved after rodding
out the regenerator to gasifier transfer leg and the cyclone
return system functioned without excessive leakage. At 06.1O
the gulf streaming trials were stopped. Some of the erratic
fines transfer problems were caused by lumps of carbon in
the transfer line from the cyclone drain.
The unit gradually lined out after the unsettled period and
at 18.00 bed material, dust and gas samples were collected
before trials commenced by switching fehe fuel supply from
the left hand sidewall injector to the injector through the
- 252 -
-------
distributor without any significant effects upon performance.
At 19.50 the centre sidewall injector supply was transferred
to the distributor injector leaving one sidewall injector on
the right hand side. About 40 minutes later the boiler SO2
line had risen about 20 ppm together with a small rise in
the gasifier temperature.
21.6.73 (Day 16)
Some adjustments were made with the fuel supplied through
the injector in the distributor but increased flow produced
higher boiler S02 levels showing that 120 kgs/h was the
maximum throughput with this single outlet fuel injector.
Some problems were encountered with the regenerator air rate
which for some reason could not be raised beyond 30 m3/h
(17.6 ft3/m) with all the control valves open. The regener-
ator performance of less than 6O% sulphur removal was caused
by this limited air supply and the stone sulphur level was'
apparently building up due to the inability of the regenerator
to adequately strip the stone. Samples of bed material and
dust from the various collection points were taken at 1O.15
before a retrial with the total fuel supply fed through
the single outlet fuel injector confirmed the previous
result of higher boiler S02 levels.
The behaviour of the unit was limited by the regenerator air
supply and before burning out and investigating the regenerator,
preparations were made to carry out tests at lower bed depths
to provide further data and at the same time provide an
increased regenerator air rate. Material was withdrawn until
a bed depth of 4O cms (15.7 ins) was reached and the unit
allowed to level out.
22.6.73 (Day 17)
Problems were encountered with the fines return system and
the increase in material collected at the boiler suggested
some cyclone drain obstruction. The fuel injector through
the distributor was retracted without trouble so that
preparations could be completed for the burn out which was
started at 12.25 and by 15.25 most of the carbon had been
burnt out. The unit was put onto combusting conditions to
raise the temperature to 925°C so that a reasonably
prolonged shut down could be tolerated whilst the regenerator
distributor was removed. The bore of the regenerator was
quite clear and there were some glazed 1.5 mm (.06 ins)
thick deposits around the lower wall area. The distributor
- 253 -
-------
was generally clear apart from some local deposits between
the nozzles but these would not have caused any fluidisation
problems. The distributor was replaced without the silicon
carbide spacer ring so returning to the distributor config-
uration of Run 5.
23.6.73 (Day 18)
During the early part of this day the flue gas recycle system
was stripped and cleaned. The left hand cyclone leg was
rodded out to remove any obstruction in the 50 mm (2 in) dia-
meter drain leg and the fines return control system checked
over. The pressurisation unit for maintaining the boiler
water pressure was also checked over in an attempt to locate
the problem which prevented the pump building pressure and
the performance improved after cleaning the filters and non-
return valves.
In the afternoon two pilot flame burners were installed on
each cyclone outlet stream so that SO2 samples could be
taken from each stream thereby showing any difference between
the concentrations in each cyclone outlet. This was arranged
because there was some possibility of 802 passing from the
regenerator to the gasifier by flowing up the bed transfer
passage and in such an event the S02 level in the right
hand cyclone would be greater due to the proximity of this
transfer passage to this cyclone inlet.
At 17.00 the boiler rear door was opened and 175 kgs (385 Ibs)
of material removed from the back and 66 kgs (145 Ibs)
removed from the front soot box.
24.6.73 (Day 19)
At 01.30 gasification was restarted using a molar stone feed
rate and the unit allowed to line out at 880°C gasifier
temperature and 1O20°C regenerator temperature whilst check-
ing out the fines transfer system which although operating
through the control cycle was not transferring much material.
The hot lime shooter system was started up on the left hand
cyclone entry but causes a rise of 1OO ppm in the boiler S02
level and during a comparatively short operating period the
bed level in the gasifier dropped by 51 mm (2 ins) suggest-
ing that much of the material shot into the cyclone was
carried into the boiler and not retained by the cyclone.
Various tests were made to determine if the cyclone drain
was obstructed but apparently material was draining into
- 254 -
-------
the transfer vessel and the slow rate of collection was
probably due to the low gasifier bed depth of 38 cm (15 ins)
which threw less material into the cyclone. The regenerator
cyclone dust collection rate had become small indicating
that either the right hand cyclone was not collecting much
material or else the internal drain to the transfer line was
obstructed. A high pressure nitrogen lance was inserted
down the right hand cyclone drain leg and produced a severe
disturbance in the temperature and gas composition in the
regenerator showing that the cyclone drain leg to the
regenerator was clear.
At 19.OO trials were made with the two pilot burners on the
bifurcated duct but there were some initial difficulties in
maintaining a steady flame due to irregularities in the air
supply pressure. The regenerator performance improved as a
result of the rodding with the nitrogen lance.
25.6.73 (Day 2O)
The pilot flame trials continued but it was difficult to
obtain steady conditions because of the carbon laydown in
the burner ducts which disturbed the gas flow. The infra-
red gas analyser did show some short spikes in the SO2 level
but the Wostoff analyser did not pick up these transients.
The regenerator performance improved a little after the
pressure of the nitrogen pulse transfer was reduced so
creating less disturbance in the gasifier to regenerator
transfer line at each operation.
At 22.4O there was a sharp increase in the regenerator
circulation rate shown by a sudden temperature drop and at
the same time the fines collection rate increased in the left
hand cyclone transfer vessel. This change could have been
caused by a change in limestone feed size distribution or
the clearing of some obstruction in a transfer line.
Various small problems arose during this day in the flue gas
recycle system when blockages formed in the scrubber outlet
chamber and the control valve together with obstructions in
the gasifier pressure tappings.
26.6.73 (Day 21)
At 04.OO samples of bed material and dust were collected and
the limestone feed temporarily stopped to determine the short
term effect upon boiler S02 level. After 4 hours the level
had risen from a previous average of 29O ppm to a new
average value of 4OO ppm whilst other conditions including
- 255 -
-------
bed depth remained reasonably constant. The stone feedstock
was changed to Denbighshire at O8.4O with ^ molar feed rate.
The regenerator controller experienced some difficulty in
maintaining the temperature because the renewal of stone
feed introduced fines into the bed apparently increasing the
transfer rate between gasifier and regenerator.
At 13.OO the limestone feed rate was increased to stoichmetric
and bed material was drained where necessary to maintain a
gasifier bed of about 53 cm (21 ins). The regenerator
performance was not good during the majority of this day
possibly due to irregularities in the fines within the system.
Some investigations were made into the poor regenerator
performance by varying the air rate from 29 m3/h (17 ft3/m)
to 25.5 m3/h (15 ft3/m). Initially the regenerator offgas S02
concentration remained unchanged but gradually increased
although not sufficiently to give an overall improvement in
performance.
27.6.73 (Day 22)
At OO.55 the boiler S02 level had risen by 40 ppm during the
rise in the regenerator offgas S02 concentration. At 01.35
the boiler S02 was still higher with a further increase of
20 ppm,. The regenerator air rate was increased to 30.6 m3/h
(18 ft3/m) and the trend in boiler SO2 and regenerator S02
concentration was reversed. Further trials were made with
the two pilot flames when the unit conditions steadied
around 04.00 and reasonably steady conditions prevailed
during this period. Prior to shut down the regenerator bed
was slumped so that the boiler 802 level could be measured
without any possibility of SO2 leaking up the material trans-
fer line between the gasifier and regenerator, no change was
observed.
The plant was shut down at 18.46 with nitrogen purges in the
gasifier and regenerator to prevent the ingress of air during
the cooling period which could burn out some of the carbon in
the ductwork and cyclones.
- 256 -
-------
APPENDIX C
CAFB RUN 6
INSPECTION
Gasifier and Regenerator Refractory
The gasifier refractory was in reasonable condition without
significant deterioration. The walls were originally
blackened by carbon deposits which were thin and shiny in
the lower area but thicker in the upper section particularly
near the lid (fig. C.I). The cracks in the upper concrete
were again deposited with bands of thicker carbon about 3 cms
wide. The gasifier lid hot face refractory slab was coated
with carbon and the insulation behind this concrete was
badly cracked accounting for the leakage problems experienced
during part of the run.
The transfer passages to and from the regenerator were both
clear and the refractory in excellent condition. There was
some agglomerated material in the static corners of the
gasifier transfer pocket but this would not have caused any
circulation problems.
The regenerator bore was generally clean but there were some
new cracks in the lower section and some grooves in the
concrete where small pieces had fallen away. The upper walls
were lightly deposited with a hard coating of material with
an irregular needle like surface. The silicon carbide
spacer ring which was used initially to lower the distributor
was in excellent condition with only a few local areas of
fine material firmly bonded to the inner bore.
Gasifier and Regenerator Penetrations
The thermocouples, fuel injectors and pressure tappings were
all in good order with some deposits of carbon and lime on
their exposed .portions. The centre fuel injector was
particularly deposited with a large build up of carbon which
bridged across from the injector to the refractory wall.
- 257 -
-------
Cyclones
The cyclone entries (fig. C.I) were coated with carbon and
lime on all sides with a maximum thickness of 10 mm in some
areas. The left hand cyclone entry (fig. C.2) shows the
irregular surface with some fragmented deposits suggesting
that the shooter did have some effect upon the deposits.
In some areas the deposit had peeled away from the refractory
although still firmly attached at one end.
The right hand cyclone entry (fig. C.3) showed similar deposits
and in some areas there were upstanding ridges of carbon and
lime deposits along the line of the duct. The bores of the
cyclones were deposited with carbon and lime which tended to
be thick in the upper sections.
The left hand cyclone (fig. C.4) drain leg to the external
transfer system was quite clear but the right hand cyclone
drain (fig. C.5) was blocked with fine material. This
cyclone was connected by an internal duct to the gasifier to
regenerator transfer line and this passageway was blocked
with an agglomeration of fine particles.
The two silicon carbide cyclone dip pipes are shown in
(fig. C.6) with the particularly flaky deposits on the
external surface of the tubes. The right hand tube has an
area on the right hand side corresponding to the gas
impingement area from the cyclone entry mouth.
Gasifier and regenerator distributor
The gasifier distributor was in very good condition (fig. C.7)
with some deposits within some of the nozzle outlets. The
stainless steel was undamaged and the refractory on the
distributor face was in excellent condition. (Fig. C.7)
shows one of the carbon deposits broken away from a fuel
injector lying on top of the distributor. The gasifier
distributor drain was solidly obstructed with fine material
and it had not been possible to use this drain during the
test period.
The regenerator distributor was in good condition with the
stainless steel nozzles lightly deposited on their top
faces with fine lime particles firmly bonded to the metal
(fig. C.8) The centre drain hole was obstructed in its
lower portion in spite of the nitrogen purge maintained
during the operational period. The holes in the distributor
were generally clean with only a slight deposition of fine
material in some of the holes.
- 258 -
-------
Bed material
The unit was shut down without sulphation of the bed and
(fig. C.9) shows the slumped gasifier bed after removal of
the lid. The bed was generally free of agglomerates and
was homogeneous throughout its depth. The regenerator bed
was free flowing and again was free from any agglomerates.
Outlet Ducts
The bifurcated duct was coated with carbon and lime along
the bore of the gas passages with larger deposits at the
junction between the two ducts and around penetrations such
as thermocouples and pressure tapping probes.
The regenerator outlet pipe was coated with a hard irregular
deposit (fig. C.1O) which was thickest in the duct when it
joined with the main gasifier outlet. Further downstream
the growth formation became thinner until it formed a light
coating uniformly deposited within the pipe bore.
Premix section
The air premix section situated between the bifurcated duct
outlet and the main burner provides the first stage of air
admission to the hot gas. The central hot gas duct built
from stainless steel was coated uniformly with a thin
tenacious layer of carbon deposited over all the internal
surface. The steel was in good condition without sign of
scaling or cracking.
Burner section
The main burner was undamaged although deposited with carbon
and lime in the hot gas duct. The stainless steel clad
thermocouple placed in the burner throat had burnt away.
The pilot burner was in good order with some light deposits
of lime around its flame holder.
Boiler and stack
The boiler rear end was deposited with a quantity of lime
particles (fig. C.ll) some of which were quite coarse
indicating that the cyclones had not been very effective
over part of the operational period. The entries into the
first tube pass (fig. C.12) were coated with a hard crust
- 259 -
-------
built up around their peripheries but without much
penetration into the tube bore.
The bottom corrugations of the main corrugated fire tube of
the boiler were deposited with fairly coarse material and
down the sides and top with local agglomerates of fine
material (fig. C.13).
The stack was generally clean apart from a small quantity of
material built up at the base of the stack. The boiler had
been cleaned during the shut down during day 1O and
(fig. C.14) shows the boiler rear end immediately before
cleaning.
Boiler Probe
The boiler probe shown in (fig. C.13) was coated with an
uneven deposit of lime leaving a rough surface. It is not
possible to draw conclusions from the deposits on the boiler
probe because the service conditions were not constant at
6OO°C because of some failures in the cooling compressors
during the operating period.
- 260 -
-------
Fig. C.I Gasifier cyclone inlets
Fig. C.2 L.H. cyclone inlet
- 261 -
-------
-•' -f
^sI'
R.H. cyclone inlet
Fig. C.4 L.H. cyclone
- 262 -
-------
Fig-. C.5 R.H. cyclone
Fig. C.6 Cyclone outlet pipe
- 263 -
-------
Fig. C.7 Gasifier distributor
Fig. C.8 Regenerator distributor
- 264 -
-------
Fig. C.9 Slumped Gasifier Bed
Fig. C.10 Regenerator outlet pipe
- 265 -
-------
Fig. C.ll Boiler back end
Fig. C.12 Boiler first tube pass
- 266 -
-------
Fig. C.13 Boiler fire tube and probe
Fig. C.14 Boiler backend - day 10
- 267 -
-------
RUN 6:
APPENDIX C: TABLE I.
TEMPERATURES AND FEED RATES PAGE
! OF IP
JAY.HOUR
1 .2230
1 .2330
2.0030
2.0130
2.0230
2.0330
2.0430
2.0530
2.0630
2.0730
2*0830
2.0930
2. 1030
2* 1 130
2.1230
2. 1330
2.1430
2.1530
2.1630
2.1730
2.1830
2. 1930
2.2030
2.2130
2.2230
2.8330
3.0030
3.0130
3.0230
3.0330
3.0430
3.0530
3.0630
3.0730
3.0830
3.0930
3. 1030
3 • 1 1 30
3.1230
3. 1330
TEMPERATURE* DEG. C«
GASIFIER
862.
955.
886.
880.
882.
871.
860.
870.
868*
868*
870.
870.
872.
876.
868.
861.
868.
872.
869.
865.
880.
898.
901.
90J.
892.
893.
898.
912.
900,
895*
898.
928*
918.
910.
910.
908.
910.
911.
920.
910.
REGEN.
658*
950.
965.
1060.
1055.
1052.
1052.
1053.
1052*
1055.
1045*
1047.
1049.
1049.
1050.
1049.
1049.
1049*
1050.
1051.
1052.
1050.
1051.
1031*
1021*
1050.
1051.
1052*
1058.
1051.
1050.
1052*
1060.
1050.
1050.
1050.
1051*
1052.
1051.
1052*
RECYCLE
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
68*
65.
65.
65.
65*
65.
65*
65*
68.
69.
69.
69.
69.
69.
FEED RATE KG/HR
OIL
158.7
175.1
179.3
178.0
183.8
183-0
185.5
185.0
186.7
187.1
185.9
189.2
189.6
190.0
186.7
189.6
190.4
190.0
188.3
188.3
188.7
190.0
189.2
186.7
189*6
188.7
188 • 7
188*7
187.5
187.5
188.7
189.6
188.3
187.5
187.9
188.7
188.3
190.0
192.5
192.5
STONE
1 1 .8
5.9
0.
0.
0.
7.7
16.3
13*6
13.2
13.6
14.5
10.4
9.5
10.4
1 1.8
15.9
1 1*3
11 .3
15.0
16.3
17.7
19.5
15*4
16.3
18.1
16.3
18.1
17.2
16.8
17.2
19.1
18.1
15.9
11.3
16.8
13.6
17.2
17.2
12.2
14.5
- 268 -
-------
APPENDIX C: TABLE I.
RUN 6: TEMPERATURES AND FEED RATES PAGE
2 OF 12
DAY.HOUR TEMPERATURE* DEG. C.
GASIFIER REGEN. RECYCLE
FEED RATE KG/HR
OIL STONE
3. 1430
3. 1530
3. 1630
3. 1730
3. 1830
3. 1930
3.8030
3.2130
3.2230
3.2330
4.0030
4.0130
4.0230
4.0330
4.0430
4.0530
4.0630
4.0730
4.0830
4.0930
4. 1030
4. 1 130
4.1230
4.1330
4. 1430
4. 1 530
4.1630
4. 1730
4. 1830
4. 1930
4.2030
4.2130
4.2230
4.2330
5.0030
5.0130
5.0230
5.0330
5.0430
5.0530
908.
905.
905.
898.
902.
90S.
910.
910.
908.
912.
910.
918.
891 .
920.
912.
925.
922.
918-
920.
928.
918.
918.
882.
878*
888.
912.
905.
902.
921.
911.
913.
918.
913.
908.
910.
918.
921 .
930.
928.
895.
1061 .
1069.
1078.
1079.
1088.
1084.
1085.
1082.
1085.
1082.
1081 .
1080.
1085.
1085.
1082.
1084.
1083.
1083.
1081 .
1082.
1085.
1082.
1083*
1082.
1082.
1083.
1082.
1081.
1083*
1082.
1082.
1082.
1082.
1082.
1082.
1082.
1085.
1085.
1082.
1080.
70.
70.
70.
70.
70.
69.
69.
70.
68.
70.
70.
70.
60.
60.
70.
70.
70.
70.
70.
68*
68.
68.
70.
69.
69.
70.
69.
69.
68.
65.
67.
70.
67.
65.
62*
62.
62.
62.
70.
77.
192.9
192.0
192.0
192.9
192.0
193.7
192.9
191 .2
194.5
191.6
193.3
192.0
192.5
194.5
194.5
191.6
185.5
190.0
191.6
193-7
192.0
192.0
192.9
192.9
192.0
192.0
191.2
192.0
191.6
193-3
191.6
192.0
187.1
192.5
199.5
190.8
190.8
191.2
192.0
190.4
14. 1
13.2
14.5
19.5
24.9
22.7-
21 .3
19.5
PI .3
17.7
22.2
19.5
6.8
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
1 1.8
14.5
14. 1
14. 1
11.3
1 3. 6
17.7
13.6
15.9
18*6
15.4
11*3
15.0
14.5
14. 1
- 269 -
-------
RUN 6S
APPENDIX C: TABLE
TEMPERATURES AND FEED RATES
PAGE 3 OF 1?
lAY.HOUR
TEMPERATURE* DEC. C.
GASIFIER REGEN. RECYCLE
5.0630
5.0730
5.0830
5.0930
5. 1030
5.1130
5.1230
5.1330
5. 1430
5.1530
5. 1630
5.1730
5.1830
5.1930
5*2030
5.2130
5.2230
5.2330
6.0030
6.0130
6.0230
6.0330
6.0430
6*0530
6.0630
6.0730
6.0830
6.0930
6. 1030
6.1130
6.1230
6.1330
6*1430
6*1530
6.1630
6.1730
6.1830
6.1930
6.2030
6.2130
889.
896.
908.
899.
890.
898.
898.
910.
898.
900.
889.
891 .
895.
891 .
890.
888.
894.
890.
896.
901 .
898.
897.
886.
897.
908.
904.
900.
902.
918.
900.
910.
911.
898.
898.
885*
895.
903.
916*
893.
1081 •
1082.
1082.
1081 .
1 080 .
1081*
1082.
1083.
1081 .
1081 •
1080.
1082.
1080*
1081 •
1081.
1081.
1079.
1080.
1082.
1081 .
1081*
1080.
1080*
1080.
1080.
1080*
1080.
1080.
1081 •
1079.
1079.
1080.
108L
1081*
1081 •
1084.
1083*
1081 •
MISSED
1080.
78.
70.
70.
60.
70.
70.
70.
70.
69.
69.
68.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
69.
70.
70.
70.
70.
70.
70.
70.
68*
DATA READING
70.
FEED RATE KG/HR
OIL
191.2
191 .2
190.4
189.6
195-8
192.9
191.2
189.6
189.6
191 .6
190.0
190.8
190.4
190.8
189.6
189.6
188.3
190.4
189.6
189.6
188*3
187.5
191.6
189.6
188.3
189.6
189.6
189.6
193.3
187.9
188.7
189.2
188.7
190.4
194*1
190.8
197.0
193.7
190.8
STONE
13.6
14. 1
18.6
14.5
14.5
16.3
18. 1
18. 1
19.1
17.2
18.6
16.3
12.7
12.7
16.3
15.0
13.2
13.2
15.0
11.8
14- 1
15.4
25*4
18.6
20.4
23*6
19.1
26.8
12.7
22.7
21.3
16.3
22.2
26*8
19.5
26.8
15.0
24.5
20*0
- 270 -
-------
APPENDIX Ct TABLE I.
RUN 6: TEMPERATURES AND FEED RATES PAGE
4 OF 12
JAY.HOUR
6.2230
6.2330
7.0030
7.0130
7.0230
7.0330
7.0430
7.0530
7.0630
7.0730
7.0830
7.0930
7. 1030
7.1 130
7. 1230
7. 1330
7. 1430
7.1530
7. 1630
7.1730
7. 1830
7. 1930
7.2030
7.2130
7.2230
7.2330
8*0030
8.0130
8.0230
8.0330
8.0430
8.0530
8.0630
8.0730
8*0830
8.0930
8.1030
8 . 1 1 30
8. 1230
8.1330
TEMPERATURE* DEG. C.
GASIFIER
897.
890.
881.
900.
898.
902.
907.
902.
911.
891.
900.
899.
898.
909.
910.
910.
912.
910.
914.
912.
910.
920.
915.
916.
915.
896.
904.
910.
894.
90S.
90S.
905.
905.
907.
908.
908*
900.
899.
910.
906.
REGEN.
1080.
1045.
1056*
1081 •
1079.
1080.
1070.
1079.
1072.
1079.
1081 .
1080.
1075.
1081.
1079.
1070.
1079.
1080.
1079.
1073.
1072.
1078.
1081 •
1080*
1080.
1079.
1080.
1081 *
1072.
1080.
1080*
1080*
1081.
1085.
1081 •
1080.
1082.
1083.
1084.
1080.
RECYCLE
70.
70.
71.
68.
70.
70.
69.
68*
67.
64*
63*
64.
61.
60.
60.
60.
60.
60.
61.
61-
61.
61.
61.
65*
68.
68*
67.
65.
63.
62.
65.
68*
68.
68.
69.
70.
70.
70.
70.
70.
FEED RATE KG/HR
OIL
192.9
192.0
194.1
193.7
191.6
192.5
192.9
191.6
191.2
190.8
191 .2
190.8
192.0
191.6
192.5
192.5
193.3
192-0
192.0
191.2
193-7
187.9
191 .2
191.2
189.6
202.8
203-2
199.1
192.5
192.0
192.5
192.5
192.0
192.5
192.0
192.0
192.5
192.5
192.5
191 .6
STONE
20.0
12.7
24.9
26.3
18.1
23.1
19.1
24.9
18*1
22.7
20.9
15.9
1 5.0
11 .3
5-9
6.8
7.3
10.0
10.9
10.9
5.9
6.4
5.4
6*4
5.4
6.8
5.4
6.8
7.3
6.8
6.4
5.4
5.9
7.3
7.7
7.7
5.9
5.9
5.9
5.9
- 271 -
-------
RUN 6:
DAY.HOUR
8*1430
8. 1530
8. 1630
8*1730
8*1830
8.1930
8 • 20 30
8.21 30
8.2230
8.2330
9.0030
9 * 0 1 30
9*0230
9.0330
9.0430
9.0530
9.0630
9.0730
9*0830
9.0930
9* 1030
9*1130
9*1230
9. 1330
9*1430
9*1530
9* 1630
9.1730
9.1830
9 . 1 9 30
9.2030
9.2130
9.2230
SHUT
10.2130
10.2230
10*2330
910.
900.
910*
895.
885.
894.
902.
912.
91 1 .
912.
912.
899.
899.
900.
903.
905.
908.
906.
898.
902.
898.
899.
900.
891.
888.
891.
898.
880.
90S*
910.
920.
906.
891.
DOWN AT
892.
899.
898.
APPENDIX
TEMPERATURES AND Fl
TEMPERATURE* DEG.
GASIFIER REGEN. Rl
1085*
1082*
1079.
1080.
1080*
1084.
1079.
1082*
1082.
1085*
1086*
1083*
1083.
1081 •
1083.
1085.
1088.
1087.
1088*
1089.
1086*
1085.
1096.
1080*
1084.
1086.
1088*
1079.
1070.
1069.
1070.
1062.
1063*
9.2230 FOR
1057.
1070.
1070.
: TABL E
D RATES
c.
CYCLE
70.
70.
70.
70.
70.
66*
67.
66*
62.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
69*
64*
23 HOURS
70.
69*
70.
I •
PAGI
FEED
OIL
191.6
192.5
192.9
181 .3
173.1
169.4
169*8
167.3
171 .9
169.4
169*8
169.8
170.6
170.6
170.6
170.6
171 .0
171.0
171.0
171 .4
163*2
163.6
164.4
166*5
169.0
167.3
166.5
176.4
175.1
156-6
164*4
165.7
165.7
170.6
177.2
178.9
5 OF 1?
RATE
KG/HR
STONE
4.5
7.7
7.7
8.2
9.5
10.4
5.4
0
4
5-
6.
9-
6.
7.
5.
5.
4.
5.
6.
7.
7,
5
8
7
4
4
5
9
4
3
7
7.7
7.3
9.1
9.1
10.4
9.5
11.3
9.1
12.2
13.2
14.5
11 >3
9.1
13*6
23.1
26.3
20.9
- 272 .-
-------
APPENDIX C: TABLE I.
RUN 6: TEMPERATURES AND FEED RATES PAGE
6 OF
DAY. HOUR
.0030
.0130
• 0230
• 0330
.0430
• 0530
• 0630
.0730
.0830
• 0930
. 1030
• 11 30
. 1230
• 1330
• 1430
. 1 530
• 1630
• 1730
• 1830
• 1930
• 2030
• 2130
.2230
• 2330
2.0030
2.0130
2.0230
2.0330
2.0430
2.0530
2.0630
2-0730
2.0830
2.0930
2. 1030
2.1 130
2.1230
2. 1330
2. 1430
2.1530
TEMPERATURE* DEG. C-
GASIFIER
89R.
898.
892.
889.
889.
901 .
890.
904.
890.
882.
880.
880.
880.
890.
890.
881 •
886.
888.
900.
924.
910.
885-
865.
870.
878.
883.
899.
892.
898.
890.
893.
889.
887.
878.
901.
899.
900.
899.
905.
900.
REGEN.
1074.
1080.
1079.
1080.
1078.
1079.
1080*
1080*
1078.
1080.
1072.
1072.
1072.
1052.
1070.
1080.
1060.
1056.
1080.
1080.
1070.
1080.
1065.
1066.
1061.
1080.
1080.
1078.
1064.
1079.
1079.
1070.
1070.
1086.
1085.
1067.
1064.
1065*
1065.
1048.
RECYCLE
70.
70.
70.
69.
69.
69.
68.
67.
65.
70.
68.
68.
65.
65.
69.
68.
68.
68.
68.
67.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
69.
69.
70.
70.
70.
71.
70.
70.
70.
FEED RATE KG/HR
OIL
178.4
175.6
172.7
171.9
178.4
175.6
171 .9
169.8
171 .0
171 .4
173.5
173.1
174.3
173. 1
172.7
172.7
172.7
173.1
170.6
173.1
174.3
170.6
171.0
169.8
169.4
170.2
169.8
169.4
173- 1
173.5
169.0
170.2
169.4
169.8
170.2
171 .0
171 .9
170.2
171.0
171.4
STONE
17.7
23. 1
27.2
26.8
20.9
12.7
29.9
29.5
26.8
30.8
29.0
29.0
29.0
28.6
31 .3
29.5
29.9
31 .8
27.2
21.3
0.
15.9
20.9
29.9
21.8
25.4
12.2
23. 1
30.4
29.5
24.0
24.5
28. 1
29.9
20.0
18. 1
29.9
28. 1
28.6
24.5
- 273 -
-------
APPENDIX Ct TABLE
RUN 6: TEMPERATURES AND FEED RATES
PARC 7 OF 12
DAY.HOUR TEMPERATURE* DEG. C-
GASIFIER REGEN. RECYCLE
FEED RATE KG/HR
OIL STONE
12. 1630
12.1730
12. 1830
12. 1930
12.2030
12.2130
12.2230
12.2330
13.0030
13.0130
13.0230
13.0330
13.0430
13.0530
13.0630
13.0730
13.0830
13.0930
13. 1030
13. 1 130
13. 1230
13. 1330
13. 1430
13. 1530
13. 1630
13. 1730
13. 1830
13. 1930
13.2030
13.2130
13.2230
13.2330
1 4.0030
14.0130
14.0230
14.0330
14.0430
14.0530
1 4.0630
14.0730
883.
861 •
871 .
870.
870.
871.
881.
882.
888.
881 .
880.
875.
883.
889.
876.
882.
872.
870.
870.
864.
867.
879.
892.
890.
894.
902.
900.
904.
919.
902.
902.
881.
880-
881 .
888.
881 .
878.
881 .
895.
900.
1076.
1068.
1075.
1078.
1078-
1076.
1076.
1076.
1072.
1070.
1071 .
1049.
1073.
1068.
1073.
1061 .
1065.
1079.
1080.
1079.
1079.
1082.
1078.
1075.
1072.
1074.
1078.
1070.
1068.
1070.
1069.
1070.
1070.
1069.
1070.
1068*
1070.
1070.
1070.
1072.
71 .
72.
71.
72.
i2.
72.
72.
71.
71.
71 .
71.
71.
71.
70.
71.
71.
7S.
71.
72.
72.
72.
70.
72.
72.
72.
72.
72.
72.
71.
72.
72.
72.
71.
71 .
71.
72.
72.
70.
71.
71.
170.2
170.6
170.6
171.0
170.2
171 .4
169.0
169.0
168.6
170.2
170.6
170.6
166. 1
169.4
1 69 .8
165.7
172.7
169.8
170.2
170.2
170.6
170.6
170.2
170.6
171.0
170.2
170.2
170.2
165.7
167.7
171.0
171.0
173.5
174.3
174.3
173-1
173.9
176.4
175.6
173.5
23.6
18. 1
22.2
17.7
17.2
20.4
16.3
19.5
21 .3
16.3
24-5
18.6
21 .3
20.0
20.4
30.4
21 .3
25.9
19. 1
22.7
23. 1
22.7
16.3
11.3
16.8
15.9
19. 1
19. 1
17.7
16*8
20.4
18.6
15.9
16.8
15.4
10.4
15.4
18. 1
16.8
20.0
- 274 -
-------
APPENDIX C: TABLE I.
RUN 6: TEMPERATURES AND FEED RATES PAGE
8 OF 12
DAY. HOUR
14.0830
1 4.0930
14. 1030
14. 1 130
14. 1830
14. 1330
14. 1430
14. 1530
14. 1630
14. 1730
14. IB 30
14. 1930
14.2030
14.2130
14.2230
14.2330
15.0030
15.0130
15.0230
15.0330
15.0430
15.0530
15.0630
15.0730
15.0830
15.0930
15. 1030
15.1 130
15.1230
15. 1330
15. 1430
15. 1530
15. 1630
15.1730
15.1830
1 5 . 1 9 30
15.2030
15.2130
15-2230
15.2330
TEMPERATURE* DEG. C«
GASIFIER
901.
888.
872.
872.
869.
872.
873.
869.
856.
859.
850.
362.
869.
865.
860.
865.
878.
878.
878.
859.
862.
845.
855.
866.
872.
872.
879.
873.
867.
869.
872.
870.
870.
865.
865.
859.
880.
878.
871.
869.
REGEN.
1072.
1068.
1075.
1059.
1062.
1069.
1062.
1063.
1055.
1060.
1061 •
1060.
1053-
1070.
1051 •
1053«
1081.
1078.
1080.
1050.
1058*
1052.
1080.
1088.
1070.
1040.
1038.
1042.
1045.
1051.
1051 .
1055.
1050.
1049.
1060*
1060.
1059.
1061 .
1050.
1055.
RECYCLE
70.
70.
70,
70.
70.
70.
70.
70.
71.
70.
70.
72.
71.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
71.
72.
70.
70.
72.
70.
70.
70.
70.
70.
70.
71.
71.
70.
72.
FEED RATE KG/HR
OIL
174.3
167.3
176.8
176.4
176.8
176.8
176.8
177.6
177.2
177.6
177.2
177.6
177.6
178-0
174.7
176.8
179.3
178.0
180.9
184.2
188.7
191 .2
188.3
188.3
189.6
188.3
182.2
178.0
177.2
177.2
173.5
174.7
175.6
175. 1
174.7
176.8
176.0
173.5
172.3
174.3
STONE
21 .3
13-2
15.4
15.0
13.2
14.5
14.1
12.7
1 1 .8
16*8
20.9
16.3
15.0
16.8
15.0
11.3
15.9
19.1
16.8
17.2
16.3
13-6
13-2
16.8
16.3
14.5
16.3
16.8
14. 1
15.9
13.2
13.6
12.2
21 .8
19.5
17.7
18.6
16.8
18.6
16.8
- 275 -
-------
RUN 6:
APPENDIX C: TABLE I.
TEMPERATURES AND FEED RATES PAGE
9 OF 12
DAY. HOUR
16.0030
16.0130
16.0230
16.0330
16.0430
16.0530
16.0630
16.0730
16.0830
16.0930
16. 1030
16. 1 130
16. 1230
16. 1330
16. 1430
16. 1530
16. 1630
16. 1730
16.1830
1 6 . 1 9 30
16.2030
16.2130
16.2230
16.2330
17.0030
17.0130
17.0230
17.0330
17.0430
17.0530
17.0630
17.0730
17.0830
17.0930
17. 1030
1 7 . 1 1 30
TEMPERATURE* DEG. C«
GASIFIER
870.
874.
872.
890.
880.
878.
871.
880.
880.
882.
880.
871 .
871.
871 .
889.
866.
861 .
879.
866.
871.
874.
868.
880.
884.
890.
890.
888.
878.
880.
883.
875.
880.
873.
883.
876.
872.
REGEN.
1055.
1057.
1058*
1062.
1056.
1058*
1057.
1057.
1059.
1057.
1059.
1060.
1070.
1069*
1065.
1061 .
1066.
1068.
1059.
1062.
1068.
1070.
1072.
1072.
1079.
1052.
1062.
1062.
1063*
1061 .
1060.
1055.
1058.
1055.
1058.
1052.
RECYCLE
72.
70.
70.
70.
70.
70 *
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
FEED RATE KG/HR
OIL
173.9
173.5
176.0
168. 1
166.5
171.0
169.8
169.8
170.2
169.4
169.4
166.5
166. 1
165.3
164.8
164.8
165.3
165.3
165.7
165.3
i65.3
164.8
164.8
164.8
165.3
166.9
167.7
165.3
168.6
168.6
168.6
169.0
167.7
166. 1
164.8
164.8
STONE
17.7
16.3
18.1
5.9
0.9
2.2
9. 1
4. 1
1.3
0.9
4* 1
5.0
7.2
22.2
19. 1
19. 1
24.0
10.9
15.4
23. 1
21 .8
25.9
20.4
17.2
17.2
15.4
13.2
24.0
22.7
20.9
18.6
15-0
24.5
18.6
15.9
18.1
SHUT DOWN AT 17.1130 FOR 40 HOURS
- 276 -
-------
RUN 6:
APPENDIX C: TABLE I.
TEMPERATURES AND FEED RATES PAGE 10 OF 12
DAY. HOUR
19.0430
19.0530
19.0630
19.0730
19-0830
19.0930
19. 1030
19. 1 130
19. 1230
19. 1330
19. 1430
19. 1530
19. 1630
19. 1730
19.1830
19. 1930
19.2030
19.2130
19.2230
19.2330
20.0030
20.0130
20.0230
20.0330
20.0430
20.0530
20.0630
20.0730
20.0830
20.0930
20. 1030
20. 1 130
20. 1230
20. 1330
20. 1430
20. 1530
20. 1630
20. 1730
20. 1830
20. 1930
TEMPERATURE* DEC. C.
GASIFIER
882.
886.
880.
879.
881.
879.
882.
871.
868.
872.
875.
895.
890.
872.
866.
872.
870.
862.
866.
878.
880.
882.
880.
880.
880.
880.
889.
886*
879.
880.
882.
877.
866.
865.
872.
873.
870.
874.
884.
888.
REGEN.
1079.
1079.
1080.
1081.
1079.
1080*
1068.
1059.
1060*
1059.
1060.
1064*
1060.
1060*
1059.
1059.
1059.
1059.
1056.
1060.
1060*
1060.
1056.
1060.
1060.
1060.
1060*
1060.
1060.
1062.
1060*
1060.
1060.
1060.
1061 .
1060*
1065.
1060*
1080.
1087.
RECYCLE
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
FEED RATE KG/HR
OIL
166.9
167.3
66.9
66.5
67.7
68* 1
68. 1
70.2
171 .0
172.7
173.5
170.2
165.3
171 .4
169.0
168. 1
168. 1
169.4
170.6
168.6
168. 1
165.7
171 .0
168.1
168. 1
168. 1
168-1
167.7
166.9
168.1
168. 1
168.6
168. 1
169.4
168.6
169.0
168.6
169.0
169.0
169.4
STONE
22.2
13.2
15.9
1 5.9
14. 1
14. 1
16.3
15.9
15.9
17.2
17.2
1 4.5
15.4
16.3
13.6
12.7
IB. 1
17.2
14. 1
16.3
13-2
12.7
1 1.3
1 1 -3
13.2
15.0
11 .3
10.9
21.3
14. 5
10.9
10.9
15.4
14.5
8.6
8.2
16.3
20.4
20.9
23.6
- 277 -
-------
RUN 6:
APPENDIX C: TABLE I.
TEMPERATURES AND FEED RATES PAGE 11 OF 12
DAY. HOUR
20.2030
20.2130
20.2230
20.2330
21 .0030
21 .0130
21 .0230
21 .0330
21.0430
21.0530
21 .0630
21 .0730
21 .0830
21 .0930
21 . 1030
21 . 1 130
21 . 1230
21 . 1330
21 . 1430
21. 1530
21 . 1630
21 . 1730
21 • 1830
21.1930
21 .2030
21.2130
21 .2230
21 .2330
22.0030
22.0130
22.0230
22.0330
22.0430
22.0530
22.0630
22.0730
22.0830
22.0930
22. 1030
TEMPERATURE*
GASIFIER
883.
888.
895.
898.
918.
902-
902.
895.
897.
905.
905.
900.
889.
885.
884.
890.
890.
890.
891.
886.
884.
880.
882.
872.
874.
871 .
885.
881 .
875.
871.
870.
872.
874.
882.
882.
880.
882.
880*
878.
REGEN
1072.
1072.
1072-
1070.
1070.
1069.
1065.
1062.
1071.
STONE
1067.
1070.
1060.
1049.
1063*
1060.
1058.
1053.
1080.
1060.
1050.
1060.
1062.
1067.
1068*
1050.
1061.
1079.
1078.
1079.
1079.
1064.
1064.
1061.
1062*
1060.
1060.
1061.
1062.
1049.
DEG. C.
. RECYCLE
70.
70.
70.
70.
70.
70.
70.
70.
70.
CHANGE
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
70.
73.
74.
74.
FEED RATE KG/HR
OIL
171.4
176.0
169.4
169.8
171.9
171.4
171.0
171 .9
169.0
173.1
171.0
170.2
176.0
171.9
171.4
172.7
173.5
171.9
173. 1
173.9
172.3
172.7
171.0
170.6
171.4
172.7
172.3
171.9
171.9
171.4
171.0
171.9
169.0
173.1
171.0
170.2
171 .0
172.3
171-4
STONE
16.8
14.5
19.1
18.6
13.2
20. 4
22.2
13.6
18.6
13.6
0.
0.
0.
13*2
14.5
14.5
12.2
18.6
17.7
7.7
15.0
16.3
18.1
17.2
24.0
15.0
17.7
16*3
15.9
15.4
17.7
17.2
16.3
4.5
3.6
5.0
5.4
3.2
2.2
- 278 -
-------
APPENDIX Ct TABLE I•
RUN 6: TEMPERATURES AND FEED RATES PAGE 12 OF 12
DAY.HOUR TEMPERATURE* DEG. C. FEED RATE KG/HR
GASIFIER REGEN. RECYCLE OIL STONE
22.1130 880. 1058. 72. 172.3 4.5
22.1230 891. 1060. 72. 170.6 0.
22.1330 888. 1056. 72. 171.9 0.
22.1430 893. 1052. 75. 171.9 0.
22.1530 877. 1050. 80. 172.7 10.0
22.1630 896. 1050. 75. 170.2 13.6
22.1730 912. 1042. 75. 169.4 15.9
- 279 -
-------
APPENDIX C: TABLE II.
RUN 6: GAS FLOW RATES
PAGE 1 OF 12
DAY.HOUR
GAS
GASIFIER
AIR FLUE GAS
RATES M3/HR
PILOT REGENERATOR
PROPANE AIR NITROGEN
1 .2230
1 .2330
2.0030
2.0130
2.0230
2.0330
2.0430
2.0530
2.0630
2.0730
2.0830
2.0930
2. 1030
2. 1 130
2.1230
2. 1330
2. 1430
2. 1530
2. 1630
2. 1730
2. 1830
2. 1930
2.2030
2.2130
2.2230
2.2330
3.0030
3.0130
3.0230
3.0330
3.0430
3.0530
3.0630
3.0730
3.0830
3.0930
3. 1030
3.1130
3- 1230
3. 1330
435-
409 .
421 .
421 .
426.
413.
401 .
401 .
401 .
402.
410.
410*
418.
419.
408.
400.
391.
400.
408.
409.
429.
439.
429.
437.
437.
436.
436.
437.
437.
438.
437.
472.
455.
454.
453.
454.
455.
453.
462.
463.
153.
163.
63.
63.
63.
63.
73.
73.
53.
53.
47.
48.
24-
59.
144.
144.
1 53.
153.
!4R.
144*
] 44.
134.
134-
144.
144*
144.
143.
143-
143.
143.
143.
143.
143.
143-
1 43.
124.
124.
124.
124.
1 14.
3-4
3.4
3.4
3.4
3.4
3.4
3.3
3.3
3-3
3-3
3.0
3-0
3.0
3.0
3.0
3-0
3.0
3.0
3.0
3.0
3.0
3.0
3.0
3.0
3.0
3.0
3.0
3.0
3.0
3.0
3.0
3.0
3.0
3.1
3. 1
3-1
3.3
3.3
3.3
3.3
30.7 11.7
31.9 10.3
31.0 11 .6
31.0 4.9
30.8 4.9
33.6 3.3
34.0 3.3
34.0 3.0
33.5 3.3
32.7 3.6
33.0 2.7
33.0 3.3
33-2
32.9
32.3
31 .9
33.3
34.3
34.6
35.6
36. 1
35-6
35.4
35.4
34.9
35.0
36.0
36.9
36.8
37.3
37.3
.3
.4
.4
.3
.3
.5
.4
.5
.5
.6
.9
.6
3.1
.8
.5
.0
>.3
.7
.7
37.7 2.1
39.5 1-1
.35
.76
.80
.63
.62
.67
.69
.68
.67
.65
.61
.64
.56
.55
.53
.50
.57
.6?
.64
.68
.71
.68
.69
.65
.68
.66
.70
.72
.78
.77
.76
• 80
.85
38.2 1.2 1.78
38.3 1.6 1.81
38.4 1.7 1.82
38.7 1.8 1.84
38.4 1.6 1«82
38.1 1*6 1.80
37.9 1-4 1-79
- 280 -
-------
APPENDIX C: TABLE II*
RUN 6: GAS FLOW RATES
PAGE P. OF 12
DAY.HOUR
GAS
GASIFIER
AIR FLUE GAS
RATES M3/HR
PILOT REGENERATOR
PROPANE AIR NITROGEN
3. 1430
3. 1530
3. 1630
3.1730
3- 1830
3.1930
3.2030
3.2130
3.2230
3.2330
4.0030
4.0130
4.0230
4.0330
4.0430
4.0530
4.0630
4.0730
4.0830
4.0930
4. 1030
4. 1 130
4.1230
4.1330
4. 1430
4. 1530
4. 1630
4. 1730
4. 1830
4. 1930
4.2030
4.2130
4.2230
4.2330
5.0030
5.0130
5.0230
5.0330
5.0430
5.0530
456.
462.
463.
464.
472.
471.
472.
471 .
471 .
471 •
471 .
472.
455.
472.
473.
464.
455.
439.
438.
447.
446.
437.
402.
401 .
410.
453.
445.
445.
454.
436.
446.
455.
455.
456.
474.
447.
446.
446.
455.
446.
115.
105.
115.
1 15.
1 15.
1 14.
1 14.
105.
105.
109.
109.
109.
201.
29.
135.
125.
125-
125.
125.
125-
135.
135.
184.
175.
165.
125.
125.
125.
125.
125.
125.
125.
125.
125.
124.
124.
124.
124.
137.
147.
3.3
3.3
3.3
3.3
3.0
3*0
3.0
3.0
3.0
3.0
3.0
3*0
3.0
3*0
3.0
3.0
3.0
3*0
3.0
3.0
3.0
3.0
3.0
3.0
3.0
3.0
3.0
3. 1
3.0
3.
3.
3.
3.
3.
3.
3.
3.0
3«0
3.1
3. 1
38.3
37.9
37.9
37.4
37.2
36.8
37.0
37. 1
36.7 0
37. 1 C
36.9 1
36.5
36*0
35.9
35.9
35.9
36. 1 J
36.4
36.4
37.3
37. 1
37.6
37.9
38.0
38-0
37.7
37.0
36.7
37.0
37.0
37.2
37.2
37.2
36.2
33-4
33.3
33.0
32.8
34.9
34.0
• 3
.1
.1
.0
• 1
.1
.0
.1
J.9
».9
.0
.2
.1
.2
• 2
.3
>.l
• 8
• 3
.6
.4
• 3
• 3
.2
.3
• 3
• 3
.2
.2
• 3
• 3
• 3
• 3
.2
.0
• 0
• 1
.2
1 .1
1 •!
• 81
.80
.81
.78
.78
.76
.77
.77
.75
.76
.76
.74
.72
.73
.72
.73
.77
.78
.75
.81
.80
.81
.82
.82
.83
• 81
.78
.76
.77
1 .78
1.79
1.79
1.79
1.74
1.59
1 .59
1.58
1 . 58
1 .66
1.63
- 281 -
-------
APPENDIX C: TABLE II .
RUN 6: GAS FLOW RATES
PAGE 3 OF 12
DAY.HOUR
5.0630
5.0730
5.0830
5.0930
5.
5.
5.
1030
1 130
1230
5.1330
5.
5.
5.
5.
5.
1430
1530
1630
1730
. IB30
5.1930
5.2030
5.2130
5.2230
5.2330
6.0030
6.0130
6.0230
6.0330
6.0430
6.0530
6.0630
6.0730
6.0830
6.0930
6.1030
1 130
1230
1330
1430
1530
1 630
1730
1830
1930
6.2030
6.2130
6.
6.
6.
6.
6.
6.
6.
6.
6.
AI R
41 1 .
422.
453.
467.
453.
468*
468.
468.
463.
468 o
454.
454.
463.
454.
454.
446.
445*
445-
446.
445.
437.
438.
438-
439.
456.
456.
455.
455.
469.
463.
455.
455.
455.
455.
455.
455.
469.
468.
464.
GAS
ER
JE GAS
147.
145.
145.
136.
135.
135.
135.
137.
139.
Ml .
135.
141 .
141 •
141 .
141 •
137.
141 .
145.
141 .
141 .
135.
137.
141 .
135.
135.
135.
133.
133.
131 .
125.
1 16.
116.
1 19.
121 •
121.
121.
109.
104.
MISSED
1 10.
RATES
PILOT
PROPANE
3. 1
3- 1
3. 1
3-4
3.4
3.4
3*4
3-4
3.4
3.4
3.4
3.4
3-4
3.4
3.4
3-4
3.5
3.5
3.5
3.5
3-5
3.5
3-5
3.5
3.5
3.5
3.5
3.5
3.5
3.5
3.5
3-5
3.4
3.4
3.4
3.5
3.5
3.5
DATA READI
3-5
M
REG
AIR
34. 1
33.5
31 .5
31.5
32.6
32.6
31 .6
36.4
40.6
37.5
38.0
37.7
39.6
36.7
37.7
38.0
37.7
38.0
38.1
37.5
37.5
37.5
36.7
37.6
36.8
37.1
36.7
36.7
37.8
38. 1
36.4
37.3
37.7
36.0
33.7
34. 1
34. 1
33.4
NG
33.5
M3/HR
NERATOR
NITROGEN
1 .9
0.9
0.9
0.9
0
0.
1
1
0
9
9
9
2
9
0.9
0.9
1 .2
0.6
0.9
0.9
1.1
1. 1
0.9
0.9
0.9
0.9
0.9
0.8
1
1
1 .4
REGEN.
VELOCITY
M/SEC
.67
.59
.50
.50
.55
.56
.54
.75
.93
.78
.80
.81
.87
.75
.79
• 81
.80
.81
.81
.78
.78
.78
.75
.80
.76
.77
.75
.75
.81
.82
.74
• 78
.80
.72
.62
.62
.63
.60
1 .61
- 282 -
-------
APPENDIX C* TABLE II.
RUN 6: GAS FLOW RATES
PAGE 4 OF 1?
DAY.HOUR
GAS
GASIFIER
AIR FLUE GAS
RATES M3/HR REGEN.
PILOT REGENERATOR VELOCITY
PROPANE AIR NITROGEN M/SEC
6.2230
6.2330
7.0030
7.0130
7.0230
7.0330
7.0430
7.0530
7.0630
7.0730
7.0830
7.0930
7. 030
7. 130
7. 230
7. 330
7. 430
7. 530
7. 630
7. 730
7. 830
7. 1930
7.2030
7.2130
7.2230
7.2330
8.0030
8.0130
8.0230
R.0330
8.0430
8.0530
8.0630
8.0730
8.0830
8.0930
8. 1030
8 . 1 1 30
8. 1230
8. 1330
438.
421 .
448.
456.
448*
447.
465.
461 .
443.
456.
461 .
460.
460.
452.
452.
466*
460.
452.
452.
452.
452.
452.
452-
443.
443.
426.
434.
417.
414.
409.
418.
418.
417.
417.
417.
416.
415.
412.
410.
410.
97.
121 .
131 •
101 •
121 .
121.
108.
115*
119.
117.
128.
115.
1 14.
1 14.
1 14.
1 14.
1 14.
1 16.
1 14.
1 14.
1 14.
1 14.
1 14.
115.
117.
115.
115.
138.
144.
140.
138.
140.
140.
138.
138.
135.
135.
135.
135.
135.
3.5
3.5
3.5
3-5
3.5
3.5
3.5
3.5
3.4
3*4
3.4
3.4
3.3
3.
3.
3.
3.
3.
3.
3.
3.1
3.2
3.2
3.1
3.2
3.2
3.2
3-2
3-2
3.2
3.2
3.2
3.2
3.2
3.2
3-2
3.2
3*3
3.3
3.2
33. 5 1.3 1.61
32.8 1.1 1.53
29.2
27.3
28.8
30.2
30.4
31.0
31 .0
30.7
30.2
30.3
30*4
30*1
31 .4
.3 1-39
.5 1.33
.5 1 .40
.5 1-46
.3 1.45
.3 1 • 49
.2 1 • 48
.2 1.47
.2 1.45
.3 1.46
.5 1.47
.1 1 .44
.8 1.53
31«4 2.0 1.53
33-7 2.7 1.68
32.7 2.1 1.61
33.3 1.8 1.62
32.3
32.0
32.3
31 .7
32.2
32.0
32. 1
30.8
30.3
30.1
28.8
29.1
28.8
28.6
.5 1.55
.5 1.54
.8 1«57
.5 1.53
.8
.8
.5
.7
.8
.8
.5
?.l
.8
.8
28.6 2.1
28.3 L9
28.6 2.2
30.6 2.0
32.2 2.1
32.2 2.0
32.7 2.2
.57
.56
.55
.50
.48
.46
• 39
.44
.38
• 40
.42
• 39
• 42
• 51
• 58
• 58
• 60
- 283 -
-------
APPENDIX C: TABLE I I.
RUN 6: GAS FLOW RATES
PAGE 5 OF
DAY.HOUR
AIR
8. 1430
8. 1530
8. 1630
8. 1730
8. 1830
8. 1930
8.2030
8.2130
8.2230
8.2330
9.0030
9.0130
9.0230
9.0330
9^0430
9.0530
9.0630
9.0730
9.0830
9.0930
9. 1030
9.1 130
9. 1230
9. 133?;
9. 1430
9. 1 530
9. 1630
9. 1730
9. 1830
9* 1930
9.2030
9.2130
9*2230
SHUT
10.2130
10.2230
10.2330
403.
403.
415.
364.
347.
352.
357.
383.
383.
383.
383.
366.
365.
366.
366.
374.
366.
365.
366.
371.
371 .
366.
375.
374.
374.
374.
374.
400.
391 .
400 •
383-
375.
375-
DOWN AT
403.
412*
403.
GAS
FIER
LUE GAS
135.
125.
125.
154-
105.
105.
105.
115.
1 14.
115.
125.
134.
144.
135.
135.
164.
135.
135.
135.
135.
125.
145.
145.
135.
135.
135.
135.
135.
135.
135.
135.
144.
143.
9.2230
-
134.
144.
RAT
PILOT
E S M
REG
PROPANE AIR
3.2
3.2
3.2
3-2
3.2
3.2
3.2
3.2
3.3
3.2
3«1
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3-3
3«3
3-3
3.3
3-2
3.2
3.2
3.2
3-2
3.2
3-3
3.2
3.2
3.2
FOR 23
3.2
3.2
3.3
32.8
33-3
32-5
29. 8
31 .2
30.4
30.9
30.5
29.8
31.6
32.5
32.8
32.5
32. 1
32.4
32.3
32.3
33. 1
36. 1
29.2
32.8
31 .8
30.7
30.2
30.7
30.8
30-8
29.4
27.6
28.2
29.7
30.2
30.7
HOURS
28.6
32.6
33.7
M3/HR
NERATOR
NITROGEN
1.6
2. 1
.8
.7
• 8
.9
.8
.6
.6
.7
• 6
.6
.6
.6
.6
• 6
• 6
1 .6
2.0
1.7
.7
.7
.6
.7
.6
.6
.7
.8
.7
• 3
.5
1.8
1.8
3.1
2.0
1.7
1
REGEN.
VELOCITY
M/SEC
1 .59
1 .'63
1 .58
1 .45
1 -53
50
1 .51
1 .49
1.45
1 .54
1.58
1 .58
1.57
1.55
56
56
56
1.59
1.75
1 .42
1 . 59
1. 54
1.50
1.46
1 .48
1.48
1.50
1 .42
1 .32
1.33
1 *41
1.43
1.45
1.46
1*60
1 .64
- 284 -
-------
APPENDIX C: TABLE II.
RUN 6: GAS FLOW RATES
PAGE 6 OF 12
DAY.HOUR
GAS
GASIFIER
AIR FLUE GAS
RATES M3/HR REGEN.
PILOT REGENERATOR VELOCITY
PROPANE AIR NITROGEN M/SEC
.0030
.0130
.0230
.0330
.0430
.0530
.0630
.0730
.0830
.0930
.1030
• 1 130
. 1230
.1330
• 1430
• 1530
.1630
• 1730
.1830
• 1930
.2030
• 2130
.2230
.2330
P. 00 30
2.0130
2.0230
2.0330
2.0430
2.0530
2.0630
2.0730
2.0830
2.0930
2.1030
2. 1 130
2.1230
2.1330
12. 1430
12. 1530
41 1 .
412.
41 1.
412.
41 1 .
41 1 .
41 1 .
420.
402.
401 •
402.
407.
405.
384.
427.
427.
427.
437.
436.
427.
427.
419.
41 1 •
402.
394.
416.
402.
419.
416.
419.
416.
402.
406.
409.
427.
417.
418.
418*
409.
410.
135.
135.
135.
125.
125.
125.
125.
125.
115.
116.
115.
105.
109.
85.
135.
135-
139.
139.
139.
134.
135.
145.
161 •
161.
164.
153.
155.
154.
156-
156.
154.
154.
154.
151 .
135.
155.
145.
145.
145.
145.
3-3
3.3
3.3
3.3
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3-2
3.2
3.2
3.2
3-2
3.2
3.2
3.2
3.2
3-2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3. 1
3. 1
3.1
3.2
3.2
3.2
3.2
3.2
3.2
3.2
33.4
33. 1
33.7
35.4
31 .4
33.0
33.2
32.7
33.2
33.3
33. 1
33. 1
33.5
31 .3
26.6
26*0
24.9
29.0
24.3
28.2
31 .7
33.5
29.1
29.5
27.4
27.0
27.3
28.6
29.6 1
29.9 1
29.0
29.3
28.1
28.3
28.9
30.2
29.9
30*8
30.7
31 .3
.7 1
.9 1
.7 1
.6
.6
• 3
.6
.6
.4
.3
.4
• 4
.7
• 8
.6
• 5
.5
.4
• 4
.5
.5
.5
.8
.2
.2
2.5
1.9
2.9
3.6
3*6
.6
.2
.6
.5
2.0
.4
.2
.2
.2
.4
.63
.64
.66
.73
• 54
.61
.63
.61
• 62
.62
• 61
• 61
.65
.52
• 31
.28
.22
.40
.21
.39
.54
.64
• 43
.42
.32
.38
• 36
.47
.39
1.42
1.42
1.41
• 37
.40
.45
.46
.43
.48
.47
1 .49
- 285 -
-------
DAY.HOUR
APPENDIX C: TABLE II .
RUN 6: GAS FLOW RATES
GAS
GASIFIER
AIR FLUE GAS
PAGE 7 OF 12
RATES M3/HR RF.GEN.
PILOT REGENERATOR VELOCITY
PROPANE AIR NITROGEN M/SEC
2. 1630
2. 1730
2 . 1 8 30
2. 1930
2.2030
2.2130
2.2230
2.2330
3.0030
3.0130
3.0230
3.0330
3.0430
3.0530
3.0630
3.0730
3.0830
13.0930
13. 1030
13.1 130
13.1230
13. 1330
13. 1430
13.1530
13.1630
13.1730
13. 1830
13-1930
13.2030
13.2130
13-2230
13.2330
14.0030
14.0130
14.0230
14.0330
14.0430
14.0530
14.0630
14.0730
392.
367.
375.
383-
375.
384.
376.
384.
381.
381.
376.
381 .
385.
385.
376.
385.
383.
385.
384.
384.
384.
401.
400.
400.
410.
401 .
410.
389.
388.
405.
378.
386.
371.
374.
394.
372.
337.
380*
389.
389.
165.
179.
165.
165.
145.
165*
165.
174.
164.
164.
180.
180.
184.
184.
184*
174.
176.
174.
174.
174.
174.
164.
164.
169.
174.
165*
165.
174.
164.
172.
174.
184.
188.
191.
190.
192.
190.
189.
174.
145.
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3*4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.3
3.3
3.4
30.3 1
31. 1
30.2 1
30. 1 1
29.3 1
27.7 1
30.9 1
29.7 ]
29.0 1
31 .2 t
31 .2
30.9
30.9
30.3
30.3
29.3
29.7
29.2
28.9
28.7
28.2
28.9
29.8
28.2
31.8
31 .9 1
31.9 1
31.8 1
30. 1
30. 1 't
30.0 c
30.2 j
30.7 ?
30*0 't
28-2 '<
29.1 1
29.3 J
29.1 i
29.3 £
27.7 S
.5
1 .2
.4
.9
• 6
I .8
.6
1.2
1 .6
5.9
.6
• 2
• 6
• 2
• 2
• 2
.2
.2
.7
.8
.7
.8
.3
.2
.2
1.1
1.2
1.2
1.9
>.5
>.2
>.5
>.2
>.5
>.2
.5
>.5
>.2
>.2
>.l
.48
.50
.47
.49
. 44
.37
.51
. 44
.42
.49
.52
.47
.51
. 46
.46
.41
.43
.42
.43
• 43
.40
• 43
.45
• 37
.53
.53
.54
.53
.48
.52
.49
• 51
.52
.51
.41
.42
.47
.45
.46
• 38
- 286 -
-------
APPENDIX C: TABLE II
RUN 6: GAS FLOW RATES
PAGE R OF 12
DAY.HOUR
GAS
GASIFIER
AIR FLUE GAS
RATES M3/HP RFGFN.
PILOT REGENERATOR VELOCITY
PROPANE AIR NITROGEN M/SEC
4.0830
4.0930
4. 1030
4. 1 30
4. 230
4. 330
4. 430
14. 530
14. 630
14. 730
14. 830
14. 930
14.2030
14.2130
14.2230
14.2330
1 5.0030
1 5.0130
5.0230
5.0330
5.0430
5.0530
5.0630
5.0730
15.0830
15.0930
15. 1030
5 . 1 1 30
5. 230
5. 330
5. 430
5. 530
5. 630
5. 730
5. 1830
5. 1930
5.2030
5.2130
5.2230
5.2330
389.
387.
388.
380.
380.
371 .
371 .
380.
379.
379.
380.
380.
380.
371 .
352.
387.
385.
381 .
342.
413.
413.
397.
397.
414*
414.
414.
413.
395.
395.
387.
386.
387.
388.
387.
387.
410.
388.
387.
377.
378.
144*
154.
183.
184.
184.
184.
184.
174.
194.
194.
194.
185.
175.
175.
184.
184.
184.
174.
184.
184.
174.
174.
184.
164.
174.
175.
165.
175.
174-
175.
175.
175.
175.
175.
165.
155-
165.
165.
165.
155.
3.4
3. 1
3. 1
3. 1
3.2
3.2
3.2
3.2
3.2
3.3
3.3
3.2
3.2
3.2
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.3
3.2
3.2
3-3
3.3
3.3
2.6
3.3
3.3
3.3
3.3
3.3
3.2
3.2
3.2
3.2
3-2
3.2
27.7
26.9
29.0
30.7
31 .6
31 • 1
31 .2
31 .1
31 .0
31 .2
31 .9
31 .2
31 .2
32.7
33.7
33.9
33.0
34.2
32.0
34.8
35.4
34.7
34.0
33.9
34.2
34.4
33.8
33.8
33.7
32.0
31.7
31.6
31 .5
31 .7
30.8
30.8
30.8
31 .0
31 *0
30.7
2.1
2.3
1 .9
.9
.7
.6
• 8
.7
.7
.7
• 5
.7
.7
5.0
8.0
7.R
6.5
6.0
6.5
8.7
8.6
5-2
4.8
4.8
5.3
5.0
4.2
4.5
4.6
.5
.6
.6
.8
.4
.6
.5
.6
.4
.4
1 .3
1 .38
1 .35
1 .44
1 .49
1 .54
1.52
1 .52
1 .51
1 . 50
1 .51
1 .54
1 .52
1 .51
1 .75
1 .91
1 .90
1 .84
1 .87
1 .80
1 .98
?.01
1.82
1 .81
1 .81
1 .82
1 .78
1 .72
1 .73
1 .73
1 .53
.52
.52
.52
• 51
.49
.49
.49
.49
.48
• 47
- 287 -
-------
APPENDIX Cs TABLE II.
RUN 6: GAS FLOW RATES
PAGE 9 OF 1?
DAY.HOUR
GAS
GASIFIER
AIR FLUE GAS
RATES M3/HR REGEN.
PILOT REGENERATOR VELOCITY
PROPANE AIR NITROGEN M/SEC
16.0030
16. PI 130
16.0230
16.0330
16.0430
16.0530
16.0630
16.0730
16.0830
16.0930
16. 1030
16.1 130
16. 1230
16. 1330
16. 1430
16. 1530
16. 1630
16. 1730
16. 1830
1 6. 1930
16.2030
16.2130
16.2230
16.2330
17.0030
1 7.0J30
17.0230
1 7.0330
17.0430
17.0530
17.0630
17.0730
17.0830
17.0930
17.1030
17. 1 130
378.
387.
395.
386.
379.
370.
378«
377.
378.
379.
388.
389.
389.
387.
386.
378.
377.
377.
376.
369.
369.
352.
361 .
361 .
362.
362.
363.
353.
352.
361 .
358.
338.
393.
376.
375.
375.
155.
165.
155.
155.
161 .
174.
165.
165*
165.
164.
174.
185.
185.
185.
175.
185.
194.
194.
194.
185.
194.
185.
185.
185.
185*
68.
60.
49.
37.
31 •
25.
24.
28.
18.
193.
185.
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.1
3. 1
3*2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
30.6
30.5
30.6
30.3
30.1
30.6
30.4
30.7
30.7
30.6
30.8
30.4
30*4
30.4
30*4
30.7
31.4
31 .7
32.7
33.2
33.5
33.5
33.5
33.6
33.7 J
34.9
35.4
35.4
35.5
35.2
35.2
35.3
34.8
33.9
33.9
33-9
.4
.4
.4
.5
.4
.2
.6
.4
• 4
.5
• 4
.4
.4
.4
*4
.3
.3
.5
.6
.5
.6
• 5
.4
.8
>.0
.7
.6
.5
.6
.6
.6
.4
.5
.8
.8
.8
1 -47
1 .46
1 .47
1 .46
1 .44
1 .46
1 .47
1 .47
1 .48
1 .47
1 .47
1 .46
1 -47
1 .47
1 .46
1 .47
1.51
1.54
1.58
1.60
1 .62
1 .61
1 .61
1.64
1.66
1.67
1 .70
1.70
1.70
1.69
1.69
1.68
1.66
1.63
1*63
1.62
SHUT DOWN AT 17.1130 FOR 40 HOURS
- 288 -
-------
APPENDIX C: TABLE II.
RUN 6: GAS FLOW RATES
PAGE 10 OF \?
DAY.HOUR
GAS
GASIFIER
AIR FLUE GAS
RATES M3/HR REGEN.
PILOT REGENERATOR VELOCITY
PROPANE AIR NITROGEN M/SEC
19.55430
19 .0530
19.0630
19.0730
19.0830
19.0930
19. 1030
19.1 130
19. 1230
19. 1 330
19. 1430
19.1530
19.1630
19. 1730
19. 1830
19. 1930
19.2030
19.2130
19.2230
19.2330
20.0030
20.0130
20.0230
20.0330
20.0430
20.0530
20.0630
20.0730
20.0830
20.0930
20. 1030
20. 1 130
20. 1230
20.1330
20. 1430
20. 1530
20. 1630
20. 1730
20. 1830
20.1930
346.
349.
363.
354.
354.
328.
363-
363.
368.
368.
380.
372.
372.
372.
351.
372.
368.
360.
360.
354.
358-
358.
358.
350.
350.
356.
350.
359.
359.
348.
339.
356.
348-
347.
346.
336.
354.
354.
388.
379.
179.
189.
179.
194.
175.
177.
185.
185.
75.
65.
65.
61.
61 .
85.
81.
65.
81 .
77.
85.
75.
75.
75.
75.
75.
75.
75.
71 .
71.
65.
65.
65.
65.
55.
55.
55.
55.
65.
75.
55.
55.
3.4
3.4
3.4
3.4
3.4
3*4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.3
3.3
3.3
3.3
31-9
31*4
30*8
32.2
31 .6
31.9
31*3
30.5
31.7
29.6
30.5
30.2
31.7
30.9
31. 1
28.0
27.7
28-2
28* 1
29. 1
31 . 1
30.5
31.8
33* 1
30*9
32. 3
33. 1
33. 1
32*8
33.0
34. 1
34.5
32.5
31.8
32.0
31*6
33.0
40.5
40*2
35.7
1 .0
1 .0
• 4
• 0
.0
• 1
• 3
1 .3
1.5
1.5
1.5
1 .8
1.8
2.4
1 .8
2.1
1 .5
1 .5
1.6
1.7
1 .8
1.8
1.6
2.2
2.0
2.0
1.7 1
2.4 1
2-6 1
2.3
1.9
1.9
4.2
2.1
1.9
1 .6
2.1
1 .7
1 .8
2.0
.53
.51
. 50
.55
.51
.54
.50
.46
.5?
.43
.47
.48
.54
.53
.51
.38
.34
.36
.36
.41
.51
.48
.53
.62
.51
.57
.59
.63
.63
.62
.65
.67
.69
.56
.56
.53
.62
.93
.95
.76
- 289 •-
-------
APPENDIX Ct TABLE II.
RUN 6: GAS FLOW RATES
PAGE 11 OF 12
DAY. HOUR
GASIFI
GAS
ER
AIR FLUE GAS
20.2030
20.2130
20.2230
20-2330
21 .0030
21.0130
21 .0230
21 .0330
21 .0430
21 .0530
21 .0630
21 .0730
21.0830
21 .0930
21 . 1030
2 1 . 11 30
21 . 1230
21 . 1330
21 . 1430
21 . 1530
21 • 1630
21 . 1730
21. 1830
21 .1930
21 .2030
21 .2130
21 .2230
21 .2330
22.0030
22.0130
22.0230
22.0330
22.0430
22.0530
22.0630
22.0730
22.0830
22.0930
22. 1030
385.
390.
408.
392.
391 .
393-
374.
375.
384.
383.
374.
382.
356.
371 .
380.
379.
388.
389.
389.
371 .
355.
355.
356.
354.
364.
365.
374.
374.
374.
358.
374.
373.
356.
357.
357.
357.
366.
338.
338.
155.
155.
155.
155.
155.
155.
165.
175.
175.
STONE
175.
185*
175.
175.
175.
165.
155.
155.
155.
155.
165*
175.
175.
175.
175.
175.
175.
175.
175.
194.
185.
185.
185.
185.
185.
185.
185.
176.
176.
176.
RATE
PILOT
PROPANE
3.3
3.4
3. 1
3.3
3.2
3.2
3.2
3.2
3.2
CHANGE
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3-2
3.2
3.2
S M3/HR REGEN.
REGENERATOR VELOCITY
AIR NITROGEN M/SEC
29.7 1.6
35.1 1.6
26.4 2.0
29 • 5 1.3
32.3 2.0
29 . 9 1.3
35.0 2.0
31 .8 1.3
34.2 1.4
35.3 1 .R
34.7 1.5
34.8 1.6
31.2
30.9
33.6 J
31 .6
30*2
30.0
35.5
35.2
35.2
36.7
36.9
35.0
32. 1
31 .2
30.7
33-2
32.3
29.9
35.0
31.8
32.2
35.3
34.7
34.8
34.8
35.5
34.5
.5
.6
>.l
.9
.8
.7
?.0
.7
.6
.6
.9
.9
.8
.6
.6
.5
.4
.5
.4
.6
.5
.8
.7
.6
.3
.6
.4
• 45
.70
• 31
• 42
.58
• 44
• 70
.52
.64
• 71
.67
.67
.49
.49
.63
• 53
.46
.47
.72
.68
• 68
.76
.79
.70
.54
• 50
• 50
• 61
.56
.46
• 67
• 53
.54
.70
.67
-67
.65
.70
• 63
- 290 -
-------
APPENDIX C: TABLE II.
RUN 6: GAS FLOW RATES PAGE 12 OF 12
GAS RATES M3/HR REGEN.
DAY.HOUR GASIFIER PILOT REGENERATOR VELOCITY
AIR FLUE GAS PROPANE AIR NITROGEN M/SEC
22. 1 130
22. 1230
22. 1330
22. 1430
22. 1530
22. 1630
22. 1730
354.
354.
337.
336.
344.
374.
375.
1 75.
175.
165.
166*
169.
166.
166.
3.2
3.2
3.2
3.2
3-2
3«2
3.2
29.4
26.7
31.7
32.5
34-6
32.2
31 .6
2.2
1 .4
1.8
2. 1
1.6
1 .4
1 .3
1.45
1 .29
1.53
1 .57
1 .64
1.52
1 .48
- 291 -
-------
APPENDIX C: TABLE III.
RUN 6t PRESSURES PAGE
1 OF 1?
DAY. HOUR
1 .2230
! .2330
2.0030
2.0130
2.0230
2.0330
2.0430
2.0530
2.0630
2.0730
2.0830
2.0930
2. 1030
2. 1 130
2. 230
2. 330
2. 430
2. 530
2. 630
2. 730
2. 830
2. 930
2.2030
2.2130
2.2230
2.2330
3.0030
3.0130
3.0230
3.0330
3.0430
3.0530
3.0630
3.0730
3.0830
3-0930
3. 1030
3.1130
3.1230
3*1330
GASIFIER P. KILOPASCALS GASIFIER
GAS DISTRIB. BED BED
SPACE D.P. D.P. SP. GR.
4.5 4.0 5.5 0.90
4.5 4.0 5.2 0.90
4.5
4.5
4.5
4.5
4.5
4.4
4-5
4.4
4.4
4* 4
4.4
4.3
4.2
4.2
4.2
4.2
3.6
4.1
4.4
4.4
4.5
4.5
4.5
4.5
4.5
4.5
4.5
4.5
4.6
4.7
4.6
4*4
4.4
4.3
4.2
4.3
4.4
4.2
4.0
4.0
4.0
4.0
4.0
3.2
3*6
3.5
3.5
3.4
3.5
3.5
3.5
3.4
3.4
3.5
3.5
3.4
3.6
3.7
3.7
3.9
3-7
3.9
3.9
3.9
3.9
3.9
3.9
4.2
4.0
3.9
3.9
3.9
3.9
4*0
4.0
4*0
5.2 0.90
5.2 1.00
5.1 0.95
5.2 1.00
5.1 0.90
5.2 0.95
5-5 1-00
5.7 0.95
5.4 1.00
5.4 0.95
5.5 0.95
5.5 0.98
5.5 1.00
5.6 1.00
5.6 1*00
5.3 1.00
5.1
5.2
5.1 S
5.2
5.1
5.4
5.5
5.5
5.5
5.6
5.6
5.7
5.8
6.0
5.6
5.8
6.1
5.8 P
6.0
6.1
6.2
6.2
• 00
.00
J.95
.00
.00
.00
.00
• 00
.00
.00
.00
.00
.00
.00
.00
.00
.00
1.95
.00
.00
• 00
.00
RE GEN.
BED
D.P.
6.0
6.0
6.0
6.0
6.0
6.0
6.0
6.0
6.0
6.0
6*0
6.0
6.2
6.2
6.2
6.2
6.0
5.7
5.5
5.5
6.0
5.5
5.7
7.2
7.5
7.0
6. 5
7.0
6.7
7.0
7.2
7.5
7.5
7.0
7.0
6.5
6.5
6.5
6. 5
6*5
- 292 -
-------
DAY.HOUR
APPENDIX C: TABLE III.
RUN 6: PRESSURES PAGE J? OF 12
GASIFICR P. K1LOPASCALS GASIFIER REGEN.
GAS DISTRIB. BED BED BED
SPACE D.P* D.P. SP. GR. D.P.
3. 430
3. 530
3- 630
3. 730
3. 830
3. 930
3.2030
3-2130
3-2230
3.2330
4.0030
4.0130
4.0230
4.0330
4*0430
4.0530
4.0630
4.0730
4.0830
4.0930
4. 1030
4.1 130
4. 1230
4. 1330
4. 1430
4. 1 530
4.1630
4. 1730
4. 1830
4. 1930
4.2030
4.2130
4.2230
4.2330
5.0030
5.0130
5.0230
5.0330
5.0430
5.0530
4.2
4.2
4.2
4.2
4.2
4.2
4.4
4*4
4.4
4-3
4*4
4.4
4.2
3.9
4*4
4.2
4.2
4.2
4.1
4.2
4.2
4. 1
4.1
4.2
4.1
4.2
4.2
4.2
4.4
4*4
4*4
4.4
4.4
4*4
4*4
4.4
4.4
4-5
4.7
4*4
3.9
3.9
3.9
3.7
4*0
4.0
4*0
4.0
4.0
4.0
4.0
4.0
4.0
4. 1
6.5
5.8
5.5
5.4
5.5
5.5
5.5
5.5
5.4
5.4
5.5
5.7
5.6
5.6
5.7
5.7
5.6
5.5
5.5
5.5
5.7
5.4
5.5
5.6
6.2
5.5
6*2 1
6-3 1
6*3 1
6.2 1
6.2 1
6*2 1
6*2 1
6.3
6.5
6.3
6.3
6.5
6.4
6.5
6.5
6.5
6.3
6*2
6.2
6.2
6.2
6.2
6.2
6.2
6.0
6.1
6*2
6.3
6.2
6.2
6.2
6*3
6.5
6.5
6.6
6. 1
6.1
6*1
5.8
6.2
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
• 00
.00
.00
.00
. 10
. 10
.00
.00
.00
.00
.00
.05
. 10
.10
. 10
.09
.05
.05
.05
.03
.05
.05
.10
.10
.00
.00
• 00
.00
1.00
1.05
6.2
6.2
6.3
6.5
6.7
6.7
6.5
6.5
6.5
6.7
6.7
7.0
6.7
7.0
7.0
7.2
7.0
6.7
7.0
6.5
6.5
6.5
6*0
6*0
6.2
6.5
6.7
6.7
6.7
6.7
6.7
6-7
6.7
6.7
7.2
6.7
7.2
7.0
7.2
7.0
- 293 -
-------
APPENDIX C: TABLE III.
RUN 6: PRESSURES PAGE
3 OF
GAS1F1ER P. KILOPASCALS GASIF1ER
DAY. HOUR
5.0630
5.0730
5.0830
5.0930
5.1030
5. 11 30
5. 1230
5.1330
5.1430
5. 1 530
5. 1630
5. 1730
5. 1830
5. 1930
5.2030
5.2130
5.?230
5.2330
6.0030
6.0130
6.0230
6.0330
6.0430
6.0530
6.0630
6.0730
6. 0830
6.0930
6*1030
6. 1 130
6. 1230
6. 1330
6. 1430
6. 1530
6. 1630
6. 1730
6. 1830
6.1930
6*2030
6.2130
GAS
SPACE
4*4
4.4
4.4
4.4
4.4
4.4
5.2
4.2
4.2
4.4
4.4
4.2
4.2
4-2
4.2
4.2
4.2
4.2
4-2
4.4
4.2
4.4
4.2
4.4
4.5
4*4
4.4
4.3
4.2
4*4
4.4
4.2
4.2
4.4
4.2
4.4
4.4
4.5
4.6
DISTRIB. BED BED
D.P.
5.5
5.8
6.2
6.2
6.2
6*3
5.8
6.0
6.2
6.2
6.2
6.0
6. 1
6.0
6*0
6. 1
6.1
6. 1
6.0
6.2
6.1
6.1
6.1
6.3
6-2
6.5
6.2
6.2
6.2
6.2
6.2
6.3
6.3
6.5
6.2
6.5
6.5
6.5
MI SSED
6.2
D.P. SP. GR.
6.3
6.6
6.6
6.6
6.6
6.5
6.5
6.2
6.0
5.7
6.0
6.0
6.0
6.1
6.0
6.1
6.0
6.0
6.0
6.0
6.0
6.0
6.2
6*2
6.2
6.2
6.2
6.5
6.0
6.0
5.7
5.7
6.0
5-7
5.6
5.6
5.7
5.5
.05
.05
. 10
. 10
. 10
• 10
• 00
• 00
.00
.00
.00
• 10
.05
.00
.05
. 10
.05
.05
.05
.05
.05
.05
.05
.05
.00
.00
.05
.05
.05
.00
.05
.00
• 10
.05
. 10
. 10
.00
.10
DATA READING
5.5 1.10
RE GEN.
BED
D.P.
7.0
8.0
9.0
9.0
9.0
8.5
7.0
6.2
6.7
6.P
6.2
6.5
6.0
6.2
6.0
6.2
6.2
6.P
7.5
7.5
7.0
7.0
7.0
7.0
7.0
7.0
7.0
5.5
7.0
6.7
7.0
6.2
6.2
6*2
5.7
6.7
6.2
6.2
6*0
- 294 -
-------
APPENDIX C: TABLE III.
RUN 6: PRESSURES PAGE
A OF 12
DAY. HOUR
GASIFIER P. KILOPASCALS GASIFIER
GAS DISTRIB. BED BED
SPACE
6
6
7
7
7
7
7
7
7
7
7
7
7
7
7
7
7
7
7
7
7
7
7
7
7
7
8
8
8
8
8
8
8
8
8
8
8
8
8
8
.2230
• 2330
.0030
.0130
.0230
• 0330
.0430
.0530
.0630
.0730
.0830
.0930
. 1030
• 1 130
• 1230
. 1330
. 1430
• 1530
. 1630
• 1730
• 1830
. 1930
• 2030
.2130
• 2230
• 2330
.0030
.0130
.0230
.0330
.0430
.0530
.0630
.0730
.0830
.0930
• 1030
. 1 130
. 1230
• 1330
4.
4.
4.
4.
4.
4.
4.
4.
4.
4*
4.
4.
4.
4.
4.
4.
4.
4.
4.
4.
4.
4.
4.
4.
4.
5.
5.
4.
4.
5.
4.
7.
4.
5.
5.
5.
5.
5.
5.
5.
5
5
6
6
7
6
7
7
7
7
7
7
7
7
7
7
6
7
7
6
6
6
6
7
7
0
1
9
9
0
9
3
9
0
0
0
0
0
1
0
D.
6.
6.
6.
6.
6.
6.
6.
6.
6.
6.
6.
6.
6.
6.
6*
6.
6.
6.
6.
6.
6.
6.
6.
6.
6.
6.
6.
6.
6.
6.
6*
6.
6.
6.
6.
6.
6.
5.
6.
6.
P.
0
1
3
3
3
3
5
5
5
5
2
5
2
5
1
2
2
0
0
0
0
0
0
0
0
0
0
2
2
2
2
2
2
2
2
3
0
8
0
0
D.
5.
6.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
5.
P. SP.
5
0
5
5
7
7
7
7
7
7
7
7
7
7
8
•
•
•
•
•
*
•
•
•
*
*
•
•
•
•
6 0.
6 0.
6 0.
6 1.
7 1.
7 1 .
7 0.
7 1.
7 1 .
7 1.
7 1.
5 1.
2 0.
2 1 .
2 1 •
2 1.
2 1.
2 1.
2 1 •
2 1.
2 1 .
2 1 •
0 1 •
0 1 •
2 1 .
GR.
15
20
15
10
10
05
05
05
10
10
10
10
10
10
10
90
90
90
00
00
00
90
00
00
00
00
00
95
00
00
00
00
00
00
00
00
00
00
00
00
REGEN
BED
D
6
6
8
8
8
7
7
7
7
7
7
8
7
7
7
6
6
6
6
6
6
'6
6
6
6
6
6
6
6
6
6
7
7
7
7
7
7
7
.P.
.0
. 5
.0
.0
.0
.5
.5
.5
.5
.5
.5
.0
.7
.7
.7
.5
.7
.7
.7
.7
.7
.7
.7
.7
.7
.7
.7
.7
.7
.7
.7
.0
.2
.2
.2
.2
• 2
.2
7.5
7.5
- 295 -
-------
DAY.HOUR
APPENDIX C: TABLE III.
RUN 6! PRESSURES PAGE
GAS1FIER P. K1LOPASCALS GASIFIER
GAS DISTRIB. BED BED
SPACE D.P. D.P. SP. GR.
8. 1430
8. 1530
8. 1630
8 • 1 7 30
8. 1830
8. 1930
8.2030
8.2130
8.2230
8.2330
9.0030
9.0130
9.0230
9.0330
9.0430
9.0530
9.0630
9.0730
9.0830
9.0930
9. 1030
9. 11 30
9. 1230
9. 1330
9. 1430
9. 1530
9. 1630
9.1730
9 . 1 8 30
9. 1930
9.2030
9.2130
9.2230
SHUT
10.2130
10.2230
10.2330
5.1
5.0
5*0
4.7
4. 1
4.2
4.2
4.6
4.6
5.0
5.1
5.1
5.2
5.2
5.4
5.5
5.6
5.7
5.7
5.5
5.5
5.5
5.6
5.6
5.7
5.7
5.7
6.2
6.3
6.5
6.5
6.6
6*8
DOWN AT
3.2
3.4
3.2
5.9
5.7
5.8
5.6
4-1
4.2
4.4
5.1
5.0
4.9
5.0
5.1
5.0
5.0
5.0
5.0
5.1
5.1
5.1
5.4
5.4
5.2
5.2
5.4
5.4
5.4
5.4
5.7
5.6
5*6
5.4
5.5
5.5
9.2230 FOR
6.0
5.8
5.8
5.2
5.2
5.2
5.2
5.2
5.2
5.5
5.5
5.5
5.6
5.2
5.2
5.4
5.4
5.5
5.2
5.0
5.0
5.0
5.1
5-2
5.2
5.2
5.4
5.2
5.0
5.2
5.5
5.5
5.5
5.0
4.7
4.9
23 HOURS
5.0
5.0
5.1
.00
.00
• 00
.00
.00
• 00
• 05
.05
.00
.05
.00
1 .00
1 .00
.00
.00
• 00
.00
.05
• 00
.00
.00
• 00
.05
1 .00
1 .00
1 .05
1 .05
.05
.05
• 00
.00
.05
.00
1 .00
1 .00
1.05
5 OF 12
REGEN.
BED
D.P.
7.5
8.5
7.2
6.5
6.5
6.7
7.0
6.7
7.0
7.0
6.5
6.5
6.7
6.7
7.0
7.0
7.0
6.7
7.0
6.2
6.2
6.5
7.5
7.5
7.5
7.7
8.0
8.0
7.2
7.5
7.0
7.0
6.7
6.5
6.5
6.5
- 296 -
-------
APPENDIX C: TABLE III.
RUN 6i PRESSURES PAGE
6 OF 12
GASIFIER P. KILOPASCALS GASIFIER
DAY. HOUR
• 0030
.0130
.0230
.0330
.0430
.0530
.0630
.0730
.0830
1 1 .0930
1 1 . 030
11. 130
1 1 • 230
1 . 330
1 • 430
1 . 530
1 . 630
1 . 730
1 .1830
1 .1930
1 .P030
1 -P130
1 .2230
1 .2330
12.0030
12.0130
12.0230
12.0330
12.0430
12.0530
12.0630
12.0730
12.0830
12.0930
12. 1030
12. 1 130
12. 1230
12. 1 330
12. 1430
12. 1 530
GAS
SPACE
3.4
3.2
3.2
3.2
3.2
3.1
3.0
3. 1
3.0
3.0
2.9
2.9
2.9
2.9
3.2
3.2
3. 1
3.1
3.0
3.5
3.5
3.4
3.5
3.4
3.6
3.5
3.5
3.7
3.6
3.6
3.5
3.6
3.5
3.5
3.6
3.6
3.6
3.6
3.6
3.6
DISTRIB.
D.P.
5.8
5.8
5.8
5.7
5.7
5.7
5.7
5.8
5.5
5.5
5.5
5.5
5.2
5.1
7.0
6.8
6.8
7.0
7.0
7.0
6.7
7.0
7.0
7.0
6-8
6.8
7.0
7.2
7.0
7.2
7.2
7.2
7.2
7.1
7.5
7.7
7.7
7.7
7.6
7. 7
BED BED
D.P. SP. GR.
5.4
5.5
5.6
5.8
6.0
5.8
6*0
6.0
6.1
6.0
6.0
6*0
6*2
6*1
5.7
6.0
6.0
6.0
6.0
6.0
5.5
.05
.05
.00
.05
.05
.05
.05
.05
.05
.05
.05
.05
. 10
.05
.05
.03
.05
.05
. 10
• 14
.00
6.0 1-10
6.0 1.05
6.0 1.05
6.0 1.05
6.0 1.00
6.0 .10
5.7 .00
5.6 .00
5-6 .10
5.7 .00
5.6 1 • 10
5.6 1 • 10
6.0 ^00
6*0 .00
5.7 .00
5.7 .00
5.5 .00
5.5 .00
5.5 .00
RE GEN
BED
D.P.
6.5
6.7
7.0
7.0
7.0
7.0
7.0
7.0
7.0
6.7
6.5
7.0
6.7
7.0
7.0
7.0
7.1
6.7
6.7
8.2
7.0
6.6
7.5
7.5
7.2
7.2
7.2
7.2
7.5
7.0
7.2
7.7
6.7
7.5
5.7
5.5
5.7
6.7
7.0
7.5
- 297 -
-------
APPENDIX Cl TABLE III.
RUN 6r PRESSURES PAGE 7 OF 12
GAStriER P. K1LOPASCALS 6AS1FICR REGEN.
DAY.HOUR GAS DISTRIB. BED BED BED
SPACE D.P. D.P. SP. GR. D.P.
12. 1630
12. 1730
12. 1830
12.1930
12.2030
12.2130
12.2230
12.2330
13.0030
13.0130
13.0230
13.0330
13.0430
13.0530
13.0630
13.0730
13.0830
13.0930
13. 1030
13. 1 130
13. 1230
13. 1330
13. 1430
13. 1530
13. 1630
13. 1730
13.1830
13. 1930
13.2030
13.2130
13.2230
13.2330
14.0030
14.0130
14-0230
14.0330
14.0430
14.0530
14.0630
14.0730
3.5
3*1
3.2
3.2
3.2
3.5
3.4
3.4
3.4
3.5
3.5
3.5
3.6
3.5
3.5
3.5
3.5
3.4
3.4
3.2
3.4
3.4
3.5
3.5
3.6
3.6
3.6
3.5
3.5
3.4
3.5
3.5
3.5
3-5
3.5
3.6
3*6
3.6
3.6
3.6
7.7
7.2
7.5
7.2
7.5
7.5
7.5
7.5
7.7
7.7
7.8
7.7
7.8
8.0
8.0
8.0
7.8
7.8
7.8
7.8
7.8
8. 1
8.2
8.2
8*2
8.2
8. 1
8.0
7.8
7.8
7.7
7.5
7.5
7.5
7.5
7.2
7.2
7.5
7.5
7.5
5.2
5.2
5.5
5.5
5.5
5.5
5.5
5.2
5.2
5.1
5.2
5.2
5.1
5.0
5-1
5.2
5-2
5.5
5.5
5.5
5.2
5.5
5.2
5«2
5*0
4.7
4.7
4.9
5.2
5.2
5.4
5.5
5.5
5.5
5.5
5.5
5.5
5.5
5.5
5*6
1 .00
1 .00
1 .00
1.00
1 .00
.00
• 10
. 10
.10
. 10
. 10
1 .00
1 . 10
.05
. 10
. 10
. 10
.05
.10
• 10
. 10
. 10
.10
.10
. 10
.10
.05
.05
.05
.00
. 10
.05
.00
.05
. 10
. 10
• 10
• 10
.00
.00
7.5
6.5
6.7
6.7
6.7
6.7
6.0
6.0
5.8
5-7
6.0
5.7
8.2
8.2
FJ.2
R.5
8.5
8.5
7.2
7.5
7.5
7.5
7.2
7.0
7.0
7.0
7.0
7.0
7.5
7.5
7.5
8.7
8.7
8-7
8.7
7.7
7.7
6*6
6.6
6.7
- 298 -
-------
APPENDIX C: TABLE III.
RUN 6: PRESSURES PAGE
R OF
GASIFIER P. KILOPASCALS GASIFIER
DAY. HOUR
1 4.0830
1 4.0930
14. 1030
14. 1 130
14. 1230
14. 1330
14. 1430
14. 1530
14.1630
14. 1730
14. 1830
14. 1930
14.2030
14.2130
14.2230
14.2330
15.0030
15.0130
15.0230
1 5.0330
1 5.0430
15.0530
15.0630
1 5.0730
15.0830
15.0930
15. 1030
15. 1 130
15. 1230
1 5. 1330
15. 1430
15. 1530
15. 1630
15.1730
1 5.1830
15. 1930
15.2030
1 5.2130
15.2230
15.2330
GAS
SPACE
3.6
3.6
3.5
3-6
3.5
3.5
3.5
3-4
3.5
3.5
3.5
3.6
3.5
3.5
3.5
3.7
3.9
3.7
3.7
3.9
4.0
4.0
3.9
3.9
3.9
3-8
3.9
3.9
3.9
3.9
3.7
3.7
3.6
3.7
3.7
3.6
3.7
3.6
3*6
3.6
DISTRIB.
D.P.
7.2
7.2
7.2
7.2
7.2
7.2
7.1
7.1
7.2
7.2
7.2
7.2
7.1
6.7
6.5
8.0
7.6
6.8
7.8
8.5
8.6
8-6
7.8
7.6
7.8
7.6
7.6
7.5
7.6
7.7
7.5
7.5
7.5
7.6
7.5
7.5
7.5
7.3
7.4
7.4
BED BED
D.P. SP. GR.
5.6 0.90
5.6 1.00
5.6 1.00
5.6 1.00
5.6 1.00
5.7 0.95
5.7 0.95
5.7 0.95
6.0 0.95
6.0 0.95
5.7 1.00
5-5 1.00
5.6
5.7
5.7
5.5
5.6
5.5
5.0
4.9
4.7
5.0
5.0
5.0
4.7
5.0
5. 1
5.1
5. 1
5.2
5.4
5.5
5.5
5.5
5-5
5.6
5.6
.00
.00
.00
• 00
.00
• 00
.00
• 00
• 00
• 00
.00
.00
• 00
.00
.00
.00
.00
.00
.00
.00
• 00
.00
.00
.00
.00
5.5 1.00
5-7 1.00
5.7 1.00
REGEN
BED
D.P.
6.7
6.7
6.7
8.0
7.2
7.5
7.7
8.0
8.0
8.0
8.0
8.0
8.0
8.0
8.0
8.0
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7. 5
7.5
7.5
7.7
7.7
7. 7
7.5
7.5
7.5
7.5
7.5
- 299 -
-------
APPENDIX C: TABLE III.
RUN 6: PRESSURES PAGE 9 OF 15?
GASIFIER P. KILOPASCALS GASIF1ER REGEN.
DAY.HOUR GAS DISTRIB. BED BED BED
SPACE D.P. D.P. SP. GR. D.P.
16.0030
16.0130
16.0230
16.0330
16.0430
16.0530
16.0630
16.0730
16.0830
16.0930
16. 1030
16. 1 130
16.1230
16.1330
16.1 430
16. 1530
16. 1630
16.1730
16. 1830
16-1930
16-2030
16.2130
16.2230
16.2330
17.0030
17.0130
17.0230
17.0330
17.0430
17.0530
17.0630
17.0730
17.0830
17.0930
17.1030
17.1 130
3.6
3.6
3-7
3.7
3.6
3.6
3.6
3.6
3.6
3.6
3.6
3.6
3.6
3.6
3.6
3.6
3.5
3.6
3.6
3.6
3.6
3.9
3.7
3.7
3.8
3-8
3*8
3-8
3-8
3.9
3-7
3.8
3.9
4.0
3.9
4.0
7.3
7.3
7.5
7.5
7.2
7.5
7.3
7.5
7.5
7.6
7.6
8. 1
8.2
8.2
8.0
7.7
7.8
8*0
8.0
8. 1
8.1
8. 1
8.1
8.2
8.3
8.3
8.3
8.3
8.5
8.6
8*6
8.6
8.8
8.7
8.7
8.7
5-6
5.6
5.5
5.6
5.6
5.6
5.6
5.6
5-5
5.5
5.5
5.5
5.5
5.5
5.2
5.1
4.9
4.5
4.5
4. 1
4. 1
4.2
4.5
4.5
4.2
4.2
4*0
4.2
4.2
4.2
4.2
4.4
.00
.00
.00
.00
.00
.00
• 00
.00
.00
• 00
.00
.00
.00
.00
.00
.00
• 00
.00
.00
.00
.00
.00
.00
• 00
.00
.00
.00
• 00
• 00
• 00
• 00
.00
4.2 1.00
4.5 0.90
4.2 0.90
4.2 0*90
7.7
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7. 5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
SHUT DOWN AT 17.1130 FOR 40 HOURS
- 300 -
-------
DAY.HOUR
APPENDIX C: TABLE III.
RUN 6: PRESSURES PAGE 10 OF 1?
GASIFIER P. K1LOPASCALS
GAS DISTRIB. BED
SPACE D.P. D.P.
19
19
19
19
19
19
.0430
.0530
.0630
0730
0830
0930
19.
19.
19.
19.
19.
19.
19. 1030
19. 1130
19.1230
19. 1330
1430
1530
1630
1730
. 1830
.1930
19.2030
19.2130
19.2230
19.2330
0030
0130
0?30
0330
0430
0530
0630
0730
0830
0930
1030
1 130
1230
1330
1430
1530
1630
1730
1830
1930
20
20
20
20
20
20
20
20
20
20
20
20
20
20
20
20
20
20
20
20
3.7
3.7
3.7
3.5
3.7
3.7
3.7
3.7
3.7
3.6
3.7
3.7
3.7
3.7
3-7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.9
3.7
3.9
3.9
3.9
3.9
3.9
3.9
3.7
3.6
3.6
3.6
3.9
3.9
3.9
3.9
6.8
7.5
7.5
7.5
7.6
7.7
8.0
8.0
8.0
8.0
8.0
8*0
8.2
8.2
8.3
8.5
8.5
8.5
8.5
8.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
4.0
4.0
4. 1
4. 1
3.7
3.7
3.9
3.9
3.9
4.0
4.0
4.0
4*0
4.0
4.0
4. 1
4.2
4.4
4.5
4.4
4.4
4.4
4.4
4*4
4.2
4.2
4.2
4.2
4*2
4.2
4.4
4.4
4.7
4.7
4.7
4.7
4.7
4.7
4.7
4.7
GASIFIER
BED
SP. GR.
• 00
.00
.00
.00
• 00
• 00
1.00
1 .00
0.95
0.90
1 .00
1. 10
1 .00
1 .00
1 .00
0.95
1
1
1
1
1
1.00
1 .00
• 00
.00
.00
.00
.00
.00
.00
.00
.05
.00
.00
.00
.00
.00
1.05
.00
.00
1 .00
1.00
.00
.00
1 .00
REGEN.
BED
D.P.
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7. 5
7.5
7. 5
7.5
7.5
7.5
7. 5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7. 5
7.5
7.5
7.5
7.5
7.5
7. 5
7.5
7.5
7.5
7.5
- 301 -
-------
APPENDIX C: TABLE III .
RUN 6: PRESSURES PAGE 11 OF 12
GASIFIER P. KILOPASCALS GASIFIER REGEN.
DAY.HOUR GAS DISTRIB. BED BED BED
SPACE D-P. D.P. SP. GR. D.P.
20-2030
20.2130
20.2230
20-2330
21 .0030
21 .0130
21 .0230
21 .0330
21 .0430
21 .0530
21 .0630
21 .0730
21 .0830
21.0930
21 .1030
21 . 11 30
21 . 1230
21. 1330
21 . 1430
21 • 1530
21 .1630
21 . 1730
21. 1830
21 . 1930
21 .2030
21.2130
21 .2230
21 .2330
22.0030
22.0130
22.0230
22.0330
22.0430
22.0530
22.0630
22.0730
22.0830
22.0930
22.1030
3.9
3.9
4.1
4*0
4.0
4.0
4.0
4.0
4. 1
4.J
4.0
4*0
4.0
4*0
4.0
3.9
4.0
4.0
4.0
4.0
4.0
4*0
4*0
4.0
4.0
4.0
4. 1
4.0
4.1
4.0
4.0
4*0
4.0
4.0
4. 1
4.0
4- 1
4.0
4.0
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
STONE
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
5.5
5.5
4.2
4* 5
4.5
5.0
5.0
5.0
4.7
CHANGE
5.0
4.7 (
4.7
4.7
5.0
5.0
5*0
4.7
4.7
4.7
5.0
5.0
5.0
5.2
5.2
5.1
5.1
4.7
4.9
4.9
4.7
4.7
4.7
4.9
4.7
4.7
4.9
4.7
4.7
4.9
1 .00
1 .00
1.00
0.95
0.95
0.90
0.95
0.95
0.95
3.95
3.95
.00
.05
.00
.00
• 00
.00
• 00
• 05
-05
.05
.05
• 05
• 05
.05
• 05
• 03
.05
.00
.00
.05
.00
.05
. 10
• 05
• 10
.05
.10
• 10
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
- 302 :-
-------
APPENDIX C: TABLE III
RUN 6: PRESSURES
PAGE 12 OF 12
DAY. HOUR
22.1 130
22. 1230
22. 1330
22. 1430
22. 1530
22. 1630
22. 1730
GASIFIER P. KILOPASCALS GASI FI ER
GAS DISTRIB. BED BED
SPACE
4.0
4.0
4. 1
4.2
4.2
4.?
4*4
D.P.
7.5
7.5
7.5
7.5
7.5
7.5
7.5
D.P. SP. GR.
4.7
4.6
4.6
4.6
4.7
.10
• 10
. 10
. 10
. 10
4.7 0.90
4.1 0.90
REGEN.
BED
D.P.
7.5
7.5
7.5
7.5
7.5
7.5
7. 5
- 303 -
-------
RUN 6t
APPENDIX C: TABLE I V»
DESULPHURISAT10N PERFORMANCE PAGE
1 OF 12
DAY. HOUR
1 .2230
1.2330
2.0030
2*0130
2.0230
2.0330
2*0430
2.0530
2.0630
2*0730
2*0830
2*0930
2. 1030
2*1 130
2*1230
2.1330
2* 1430
2. 1530
2. 1630
2*1730
2. 1830
2 . 1 9 30
2.2030
2.2130
2.2230
2.2330
3.0030
3.0130
3*0230
3*0330
3*0430
3*0530
3*0630
3*0730
3*0830
3*0930
3*1030
3* 1 130
3*1230
3*1330
SULPHUR GAS
REMOVAL VEL*
% M/S
92*9
85*9
84.]
83*0
81 '0
81*1
84*0
81 • 1
79*9
78*9
76*9
76*5
76*4
75*1
75*4
75*2
74*8
74.8
75*3
75*6
76*5
78* 1
78*8
77.8
79*2
80*2
79*9
80*3
80*7
80.7
81*0
80*6
81 *3
81*8
81* 1
8(9*5
80*4
79*9
78*8
78*8
.44
.53
.47
.46
.48
• 43
• 42
.44
.37
• 38
.38
• 38
• 33
.45
• 36
.34
• 35
• 38
• 39
• 36
• 43
.44
• 42
.47
• 46
• 46
• 45
• 46
• 45
.44
• 44
• 56
• 51
• 50
• 51
• 46
• 46
• 46
• 49
• 45
G-BED
DEPTH
CENT IK
62.
59.
59.
53.
54.
53.
57.
56.
55.
61*
54.
57.
58.
57.
55*
57.
57.
54.
52.
53-
54.
53«
52.
54.
55.
55.
56.
57.
57.
58*
59.
60.
57.
59.
62*
62*
60.
62.
63.
62.
AIR/
FUEL
X ST.
26.8
22.7
22.7
22*8
22.1
21.5
20.7
21.0
20*6
20.7
21.2
20.6
20.9
21.1
20.8
20.0
19.5
20*0
20.5
20.5
21.6
21.9
21.5
22.2
21.9
22*0
22*2
22.1
22.3
22*3
22.1
23.7
23*1
23.0
22.9
22*7
22.8
22.5
22.7
22.6
CAO/S
RATIO
MOL*
0.97
0*44
0*
0.
0*
0*55
1.15
0.96
0.92
0.95
1 .02
0.72
0.65
0.71
0*82
1 .09
0.78
0.78
1 .03
1.13
1 .22
1 .34
1 .06
1.14
1.25
1.13
1.25
1 .19
1. 16
1.20
1*31
1.25
1 • 10
0.79
1 .16
0*94
1.19
1.18
0.83
0.98
% CAS
TO CAO
.
-
49* 1
66*3
79.7
83.0
84. 1
81*9
96*0
91 .2
89*4
88.3
83.8
66.3
75.3
85.4
87.4
86.6
76.7
80.0
73.2
70*1
67.7
68.8
56.2
71.7
64.8
62.7
69.7
59.6
61 .5
61*2
61 .9
60.2
59.9
62*4
62*0
64.3
68.4
61.6
REGEN.
S OUT *
OF FED
P».
0.
47.0
71.7
75*3
98*6
97.9
89.0
94.7
88.2
86*9
75*0
85.3
67. 1
67.0
68*0
60.0
69.7
67.4
67.9
77.2
69*6
75.4
76.0
56.2
79.0
73.4
73.7
74*4
66.4
73.6
76.7
82.6
71 . 1
73.5
76* 1
73.0
75.8
79.2
71.3
- 304 -
-------
APPENDIX C: TABLE IV-
RUN 6: DESULPHURISATION PERFORMANCE PAGE
g OF 12
DAY. HOUR
3* 1430
3.1530
3*1630
3.1730
3.1830
3.1930
3.2030
3 • 2 1 30
3.2230
3*2330
4.0030
4.0130
4.0230
4.0330
4*0430
4.0530
4.0630
4.0730
4.0830
4.0930
4* 1030
4. 1 130
4.1230
4.1330
4. 1430
4* 1530
4* 1630
4.1730
4. 1830
4. 1930
4*2030
4*2130
4*2230
4.2330
5.0030
5.0130
5.0230
5.0330
5*0430
5.0530
SULPHUR GAS
REMOVAL VEL.
t M/S
80. 1
81*6
81 .7
82*6
81.7
82.6
83.7
83.8
84* 1
84.3
85.2
85.0
83.3
78.0
75.0
76.6
78.2
78.0
75.2
73.7
71 .5
68.0
68.6
66.6
68.8
68*9
72-6
75.7
75.5
79.4
82.4
84*3
87.2
88.7
88.5
87.7
85.9
85.6
83-7
80.4
.44
.42
.45
.44
.47
.47
.47
• 44
.44
.46
.46
.47
.63
.22
.54
.51
.49
.44
.44
.47
• 48
.46
.49
.45
.45
.47
• 44
• 43
.47
• 41
• 44
• 48
• 46
• 45
• 49
• 43
• 43
• 44
• 52
• 53
G-BED
DEPTH
CENTIM
63.
64.
64.
63*
63.
63.
63.
64.
66.
64*
64.
66.
65.
66.
60.
60.
64.
63.
63.
63.
63.
60.
57.
57.
55.
57.
60.
61 .
60.
61.
60.
61 *
60.
60.
67.
62.
62.
62.
59.
60*
AIR/
FUEL
X ST.
22.2
22.6
22*7
22*6
23.1
22.9
23.0
23.2
22*8
23.1
23.0
23.1
22.6
22.6
22*9
23*0
23.8
22.2
22.0
22.2
21 .8
21 .4
19.7
19.6
20.1
22.1
21 *9
21*9
22*5
21*4
22*2
22.7
23*1
22.5
22.5
22.2
22.3
22.2
22.6
22.3
CAO/S REGEN.
RATIO X CAS S OUT X
MOL. TO CAO
0.95
0.89
0.98
.32
• 69
.52
.44
.33
.43
.20
• 50
• 32
0*46
0.
0.
0.
0.
0.
0.
0*
0*
0.
0.
0.
0.
0.80
0.99
0.95
0.95
0.76
0.92
1 .20
0.95
1 .07
1 .21
1 .05
0.77
1 .02
0.98
0*96
73.9
67.4
73.3
74.9
77.8
67,0
76.4
80.1
85*0
69.7
75.0
101 .3
74.8
61 .6
71. 1
78.7
60.3
69.9
74.6
72.9
65*4
69. B
60.5
63.7
69.2
66*4
61.7
68*0
69.7
71.9
67.3
62.9
60.9
56.4
77.4
66.8
51.5
70.3
70.7
58.2
OF FED
77.9
77.9
84.9
83.4
87.4
76.2
86.5
88.5
88.6
83*6
85.8
82-3
78.9
74.0
79.5
88*4
70.2
78. 1
83*0
80.5
71*2
76.4
65.2
65*8
73*2
75*5
69*7
73*7
74*9
78.7
73.3
73.9
70.0
63.3
72.6
70.2
47.9
73.5
81.1
61.9
- 305 -
-------
RUN 6:
APPENDIX C: TABLE IV.
DESULPHURISATION PERFORMANCE PAGE
3 OF 12
DAY. HOUR
5.0630
5.0730
5.0830
5.0930
5.1030
5 • 1 1 30
5.1230
5.1330
5. 1430
5.1530
5.1630
5-1730
5*1830
5.1930
5.2030
5.2130
5.2230
5*2330
6.0030
6.01 30
6.0230
6.0330
6.0430
6*0530
6*0630
6*0730
6*0830
6.0930
6.1030
6 . 1 1 30
6*1230
6. 1330
6. 1430
6* 1530
6.1630
6*1730
6*1830
6* 1930
6*2030
6*2130
SULPHUR GAS
REMOVAL VEL*
X M/S
86.5
86.4
86.4
86.1
87.4
87.2
86*8
88.5
88*4
88.2
87.8
88*1
87.3
-
.45
.43
• 52
.48
.47
.51
.50
.54
• 51
.53
.46
.49
• 52
• 49
72.9 1*49
76.4 1*46
74.6
75.7
78.3
78.1
73.7
74.6
73.8
77.3
76.9
75.8
77.0
77.9
78.3
78.2
79.7
78*8
78*7
79.9
79*0
78*5
78.8
78.1
.47
.48
• 48
.48
.44
.45
.45
• 44
.50
• 49
• 48
• 48
.53
• 47
• 44
• 44
• 44
.44
.43
.44
.44
.44
78.7 1*42
G-BED
DEPTH
CENTIM
61*
64.
61 .
61.
61.
60.
66.
63.
60*
58.
60.
55.
58*
62*
58.
56.
58.
58.
58*
58.
58.
58.
60*
60*
63.
63*
60.
62.
58.
60.
55.
58.
55.
55.
51.
51 .
58*
50.
MISSED
50*
AIR/
FUEL
X ST.
20.4
20.9
22.6
23.4
21 .8
22.9
23.2
23-2
23.2
23. 1
22.7
22.5
23.1
22.7
22.7
22.3
22.5
22.1
22*3
22.3
22.0
22.2
21.8
22*0
23*2
22.9
22*8
22.7
22.9
23.5
22*7
22.7
23.0
22.6
22.1
22.5
22.4
22.7
CAO/S
RATIO
MOL*
0.93
0.96
.27
.00
0.96
.10
• 23
.25
• 31
• 17
.27
. 11
0.87
0.87
1.12
1.03
0.91
0.90
1.03
0.81
0.97
.07
.73
.28
• 41
.62
.31
.84
0.86
• 57
.47
• 12
.53
.83
.31
.83
0.99
1 .65
I CAS
TO CAO
58.7
65.2
75.7
73.4
83.7
80.8
55.6
66*6
79*7
67.7
66.4
66.6
69.0
67.4
66.1
82.5
69.1
68* 1
73.4
70.0
66.8
69.6
68*8
68*3
68*6
67.3
69*1
69.6
70.1
72.4
67.9
75.7
62.1
66.5
72.7
73*2
70*4
72.0
REGEN.
S OUT I
OF FED
58.6
65*1
71*3
68.2
73.5
70.6
53.7
75.7
84.2
75.0
72.4
72.2
79*4
70.3
69.9
89.9
73.3
72.6
78.0
74.3
72.1
74.8
69.7
72*5
73.3
73*0
72.7
72.5
73.9
74*7
70.4
69.6
64.2
65.1
54.2
68*9
67.3
67.2
DATA READING
23*0
1*36
68*8
65.0
- 306 -
-------
RUN 6t
APPENDIX C: TABLE IV-
DESULPHURISATION PERFORMANCE PAGE 4 OF 12
DAY. HOUR
6.2230
6.2330
7.0030
7.0130
7.0230
7.0330
7.0430
7.0530
7.0630
7.0730
7.0830
7.0930
7.1030
7 . 1 1 30
7.1230
7.1330
7.1430
7.1530
7. 1630
7.1730
7.1830
7.1930
7.2030
7.2130
7.2230
7.2330
8.0030
8.0130
8*0230
8-0330
8.0430
8.0530
8.0630
8.0730
8.0830
8.0930
8. 1030
8* 1 130
8.1230
8.1330
SULPHUR GAS
REMOVAL VEL.
I M/S
78.8
78.2
79.8
80.4
81.6
79.4
78.0
78.8
80.7
81 .2
82.2
82.5
83* 1
83.7
81.7
80.7
79.4
80.4
79.2
78.4
78.5
81.0
79.4
77.3
75.3
74.2
74.6
73.4
75.8
76-5
74.2
74.6
72.8
71 «8
71 .6
69.9
70.7
70.6
71 .4
71 .4
.33
.35
.43
.38
.42
.43
• 43
.43
.41
.40
.45
.41
• 40
• 39
.40
• 43
.42
• 40
.40
• 40
.40
• 41
• 41
• 39
• 41
.34
.36
• 39
• 38
.36
.39
• 37
.40
.40
• 40
• 39
.38
• 37
• 38
• 38
G-BED
DEPTH
CENTIM
48*
50.
48.
50.
53.
55.
55.
55.
53.
53.
53.
53-
53.
53.
54.
63*
63.
63.
57.
58-
58.
64.
58*
58.
58.
58.
55.
56.
53.
53-
53.
53.
53-
53.
53.
53-
53-
50.
50.
53.
AIR/
FUEL
X ST.
21 .4
20.8
21.9
22.3
22.1
22.0
22.8
22.9
22.0
22.6
22.9
22.9
22.8
22.3
22.3
23*0
22.7
22.3
22.3
22.4
22.0
22.8
22.4
22.0
22.2
19.8
20.2
20.0
20.6
20.3
20.8
20.7
20.7
20.7
20.7
20*6
20.5
20*3
20*3
20.4
CAO/S
RATIO
MOL.
1.35
0.86
.67
.77
• 23
.56
.29
.69
.23
.55
.42
.08
.01
0.77
0.40
0.46
0.49
0.68
0.74
B. 74
0.40
0.44
0.37
0.43
0.37
0.44
0.35
0.44
0.49
0.46
0.43
0.37
0.40
0.49
0.52
0.52
0.40
0.40
0.40
0.40
X CAS
TO CAO
66.2
54*0
70*5
72.2
88.9
82.1
84.6
67.9
75.0
81.1
77.3
86*2
88*6
84*3
85*6
85.0
86.2
84*0
83.7
82.8
81.7
79.5
78.0
77.5
77.1
89.5
92.2
86*8
91.8
82.0
87*7
89.8
87.5
86.2
86.8
89.5
90.7
85.8
87.7
90.9
RE GEN.
S OUT X
OF FED
63.7
44.8
54.5
57.4
71.5
76.3
75.3
65.8
69.0
72.7
72.1
78.0
78-6
74.9
81 .3
73.0
85.0
77.7
78-2
75.5
72.2
77.2
73.5
71.7
73.6
72.0
73.3
72-9
72.1
70.5
76.6
77.2
74.9
75.2
75.8
76.0
79.0
80.4
80.6
81.0
- 307 -
-------
RUN 6:
APPENDIX C: TABLE IV-
DESULPHURISATION PERFORMANCE PAGE 5 OF 12
DAY. HOUR
8* 1430
8. 1530
8* 1630
8. 1730
8. 1830
8 . 1 9 30
8.2030
8*2130
8*2230
8*2330
9.0030
9.0130
9.0230
9*0330
9.0430
9.0530
9.0630
9.0730
9.0830
9 • 09 30
9. 1030
9 . 1 1 30
9. 1230
9.1330
9. 1430
9.1530
9. 1630
9. 1730
9.1830
9. 1930
9.2030
9.2130
9.2230
SULPHUR GAS
REMOVAL VEL.
X M/S
71.3
71 .4
69.9
68.4
71.2
73.4
73.4
73.1
72.8
74.0
73.2
70.9
71.1
71.7
70.8
65.9
66.1
65.9
65.7
70.7
71.2
71.3
72.5
74*8
76.4
76*9
72*3
72.7
75.9
77.6
79.1
69.2
71.0
.36
.33
.37
.32
. 13
• 14
.16
.25
• 24
• 26
.29
.27
.29
.26
.27
• 38
• 27
• 26
• 26
• 28
.24
.29
.31
• 27
.27
.27
.28
.31
.32
• 34
.31
.30
.26
6- BED
DEPTH
CENTIM
53.
53.
53-
53.
53-
53.
53.
53.
55.
54.
53*
53.
54.
54.
55.
53.
50*
48*
50.
52.
53.
53*
50.
54*
53*
48*
50.
53.
53*
55.
50.
45.
49.
AIR/
FUEL
X ST.
20.1
19.9
20.5
19.6
19.2
19.9
20.1
22.0
21.5
21.7
21.7
20.9
20.8
20.7
20.8
21 .4
20.7
20.7
20.7
20*4
21 .3
21*0
21*8
21*4
21*0
21*1
21*3
21*5
21 *3
24*4
22.2
21*7
21.7
CAO/S
RATIO X
REGEN.
CAS S OUT X
MOL. TO CAO
0*31
0.52
0.52
0.59
0.72
0.80
0.42
0.39
0.48
0.73
0.52
0.59
0.42
0.42
0.35
0.45
0.48
0.55
0-59
0.59
0.58
0.72
0.72
0.82
0.73
0.88
0.71
0*90
0.98
1*21
0.90
0.71
1.07
83.9
86*6
86*0
79.5
83.5
87.3
87.8
90.9
83. 1
81.8
73.3
70.9
78.2
77.7
78-2
68.6
67.7
64. 1
63*7
64*9
68-8
65.2
74.1
88.0
82.1
86. 1
84.8
86*2
79.8
74.3
74.5
68.2
60.3
OF FED
77. 1
75. 7
74.9
70. 1
74.0
78.5
79.4
81*6
74.6
79.9
76.3
74-4
76-8
74. 1
76.6
74.3
72.2
69*4
74. 1
58.5
71 .4
68.2
74.6
78.6
75.8
77.2
83.7
76.0
64* 1
71.3
75.7
70.3
62.6
SHUT DOWN AT 9.2230 FOR 23 HOURS
10*2130
10.2230
10.2330
71 .6
74.7
76.3
0.94
1 .39
1.40
50.
50.
49.
21*9
21 .9
21*2
1.76
1 .93
1.52
42.2
62.5
71.6
43.3
67.6
77.9
- 308 -
-------
APPENDIX C: TABLE IV.
RUN 6: DESULPHURISATION PERFORMANCE PAGE
6 OF 12
DAY. HOUR
• 0030
• 0130
.0230
• 0330
• 0430
.0530
• 0630
• 0730
.0830
.0930
• 1030
• 1130
• 1230
- 1330
• 1430
• 1530
• 1630
• 1730
• 1830
• 1930
• 2030
• 2130
• 2230
• 2330
2.0030
2.0130
2.0230
2.0330
2.0430
2.0530
2.0630
2.0730
2*0830
2.0930
2.1030
2.1 130
2.1230
2.1330
2.1430
2.1530
SULPHUR GAS
REMOVAL VEL.
t M/S
76.4
77.3
79.1
81 • 1
81 .0
81 .7
83. 1
83.7
85. 1
85.4
84.5
82.7
82.8
83*9
84.7
86.0
85.9
85.9
84.7
82.7
82.7
80.9
81.4
83.5
84.4
85.4
85. 1
82.0
80.6
81 .8
84.0
86.3
86.2
86.5
85.2
84.6
84.3
83.8
85.2
85.6
• 39
• 40
• 39
• 35
• 35
.37
.35
• 38
.29
.30
.29
• 27
• 27
• 16
• 42
.40
• 42
• 45
.46
• 45
.44
• 43
.43
• 42
•41
• 44
• 43
• 46
• 47
• 46
• 46
• 41
• 42
• 41
• 43
• 47
• 44
• 44
• 42
• 42
G-BED
DEPTH
CENTIM
52.
53.
57.
56.
58.
56.
58.
58.
59.
58.
58.
58.
57.
59.
55.
59.
58.
58.
55.
53.
55.
55.
58.
58.
58-
60.
55.
58.
57.
51.
58.
51 •
51 •
60.
60.
58-
58.
55.
55.
55.
AIR/
FUEL
X ST.
21.7
22.1
22.4
22.5
21.7
22.2
22.5
23.4
22.2
22.0
21.7
22.0
21.8
20.8
23.4
23.5
23.5
23*8
24.2
23.4
23.2
23.3
22.9
22*7
22.4
23.3
22.7
23.7
23.1
23.3
23.7
22.6
22.8
22.9
23.8
23.3
23.1
23.4
22.7
22.7
CAO/S REGEN.
RATIO X CAS S OUT X
MOL. TO CAO
1 .29
1.71
2.05
2.03
1.52
0.94
2.27
2.26
2.04
2.34
2. 18
2.18
2.17
2.15
2*36
2.22
2.26
2.39
2.08
1*60
0.
1.21
1.59
2.29
1.67
1 .94
0.94
1.78
2.28
2.21
1.85
1 .87
2.16
2.29
1.53
1.38
2-27
2.15
2.17
1*86
69.0
55.8
66.2
65.2
69.9
68.2
65.8
62.6
61 .3
60.8
54.3
60.9
63.7
56.6
55.6
51.3
67.3
62.4
63*8
71 .6
72.8
61 .6
65.3
49.5
49.4
54.4
58.7
58.0
52.2
43.7
45.5
51 .4
52.4
39.3
61 .6
55.8
51.2
53.3
51.8
49.7
OF FED
75.2
60.9
75.6
77.2
70.8
74.9
74.4
73.5
70.0
67.7
56.9
67.0
68.5
55.1
49.7
46.2
56.5
60.7
57.8
75.6
79.8
75.1
63.3
47.5
47.5
52.5
59.3
60.5
55.1
45.1
47.0
53«8
52.6
38.7
66.4
59.7
54.0
58.3
55.8
55.2
- 309 -
-------
RUN 6:
APPENDIX
DESULPHURISATION
Cl TABLE IV.
PERFORMANCE PAGE 7 OF 12
DAY. HOUR
12. 1630
12.1730
12. 1830
12-1930
12.2030
12.2130
12.2230
12.2330
13.0030
13.0130
13*0230
13.0330
13.0430
13-0530
13.0630
13.0730
13.0830
13.0930
13*1030
1 3 • 1 1 30
13*1230
13*1330
13. 1430
13*1530
13*1630
13*1730
13*1830
13*1930
13*2030
1 3 * 2 1 30
13*2230
13*2330
14.0030
14*0130
14*0230
14*0330
14*0430
14*0530
14.0630
14.0730
SULPHUR GAS
REMOVAL VEL.
X M/S
85.3
84* 1
82*5
81*6
81*6
82*2
83*4
83.7
83-5
80.7
80.7
81.9
82.8
82.4
82. 1
83*3
84*6
85*0
82*5
82*8
84*6
83*8
83-2
80*9
78-5
77.6
77.4
75*6
69.2
51.0
54-3
58.8
63.7
62*8
61.8
61.2
62.6
64.1
59.0
58.8
.42
.39
.37
.39
• 32
• 40
• 39
• 44
• 40
.39
.43
• 43
• 46
.47
• 44
•43
*43
• 42
.42
• 42
• 42
• 43
• 46
.47
• 51
• 47
• 49
• 48
.46
• 51
• 45
• 47
• 44
• 46
• 51
• 46
• 37
• 46
• 46
• 37
G-BED
DEPTH
CENTIM
53.
53.
55.
55.
55.
55.
50.
48.
48.
47.
48.
53.
47.
48*
47.
48*
48*
53.
50.
50.
48.
50*
48.
48.
46*
43*
45.
47.
50*
53*
49.
53.
55.
53.
50.
50.
50.
50.
55.
57.
AIR/
FUEL
X ST.
22.0
20.4
21.0
21 .3
21*0
21.5
21 .3
2L9
21.9
21.5
21.2
21.7
22.5
22.1
21.5
22.5
21*4
21 .7
21.7
21.6
21.5
22.5
22.4
22.4
22*8
22.5
23.0
22.1
22*4
23* 1
21*1
21*6
20*5
20*6
21*7
20*6
18*7
20.7
21 >3
21 .3
CAO/S
RATIO
MOL.
1 .80
1 .38
1.70
1 .35
1.32
1.55
1 .26
1.50
1 .65
1.25
1.87
1 .42
1 .67
1 .53
1 .56
2*39
1 *64
1 .98
1 .46
1 .73
1.76
1 .73
1.25
0.86
1.28
1.21
1*46
1 .46
1 *39
1 .30
1.55
1 *42
1 .19
1*25
1*15
0*78
1.15
1.34
1*24
1*50
X CAS
TO CAO
42.0
47.9
53.9
49.4
53.3
52.8
55*1
57.4
60.2
41 .8
61 *2
58*7
54*2
53*6
53*9
54*0
51.9
38.7
47.0
51.0
53*6
57.2
73.2
67.7
62.6
60*8
57.0
53*1
58*5
42*4
35*9
43*5
44*2
i
50*8
47.0
42*9
49.7
46*8
47.6
47.4
REGEN.
S OUT X
OF FED
43.2
53. 1
56. 1
52.6
56.5
51.9
61.9
62.5
65.8
45.4
66*2
58.2
62.6
59.5
57.8
57.2
53.8
39.3
48.6
52.2
54.5
61*2
82.9
70.6
72.3
72.2
66*1
61*8
66*2
46.5
37.6
47.4
48.8
55.6
48.3
45.5
51.4
46*2
49.9
44.9
- 310 -
-------
RUN 6:
APPENDIX C: TABLE IV.
DESULPHURISATION PERFORMANCE PAGE
8 OF 12
DAY. HOUR
14.0830
14.0930
14. 1030
14. 1 130
14.1230
14. 1330
14. 1430
14.1530
14. 1630
14. 1730
14. 1830
14. 1930
14.2030
14.2130
14.2230
14.2330
15.0030
15.0130
15.0230
15.0330
15.0430
15.0530
15.0630
15.0730
15*0830
15.0930
15.1030
15.1 130
15.1230
15. 1330
15. 1430
15.1530
15.1630
15.1730
5* 1830
5. 1930
5.2030
5.2130
5.2230
5.2330
SULPHUR GAS
REMOVAL VEL.
X M/S
61.5 1.37
63*1 1*38
65.7 1.45
66.9 1.43
67.1 1.43
66.9 1.41
68.2 1.42
66.4
66*0
66*3
65.2
66.3
65.8
66.8
67.5
68.2
63*4
61 .0
63*4
65.4
72.1
74.4
76.5
80.0
79.9
77.5
76.9
80.0
81.3
81 .9
81.1
81 .7
81.7
81 .8
82.3
83*6
81 .0
80.0
80.5
80.5
.40
.45
• 45
.44
• 43
• 41
• 38
.36
.44
• 45
• 41
• 35
• 49
.46
• 40
• 45
.44
• 48
• 49
.47
• 44
• 43
• 42
.42
.42
.42
• 41
• 38
.40
.41
.40
• 37
.35
G-BED
DEPTH
CENTIM
63.
57.
57.
57.
57.
61*
61.
61.
64*
64.
58.
55.
57.
58.
58.
55.
57.
55.
50.
49.
48.
50*
50.
50 •
48*
50*
52.
52.
52.
53.
54.
55.
55.
55-
55.
57.
57.
55.
58.
58.?
AIR/
FUEL
X ST.
21.3
22.1
21.0
20.7
20.6
20.1
20.1
20.5
20*4
20.5
20.5
20.5
20.5
20*0
19.4
21*0
20.6
20.5
18.2
21 .2
20.7
19.6
20.0
20.7
20.5
20.7
21.6
21.2
21.3
20*8
21 .5
21 .2
21.2
21 .2
21 .2
22.0
21 .2
21.5
21 •!
20.7
CAO/S
RATIO
MOL.
.59
• 02
• 14
• 10
0.97
.07
.04
0.93
0.87
1 '23
1 .53
1 .20
1 .10
1 .23
1*11
0.83
.15
• 39
.21
• 22
.13
0.93
0.91
• 16
• 12
.00
• 17
.23
.03
• 17
0.99
.01
0.91
.62
.45
• 30
• 38
.26
• 40
1.25
X CAS
TO CAO
46.9
48.5
39.5
50.3
50*0
50.7
47.2
52.6
47.6
51 -2
48*6
48*5
48*0
34.8
50.6
50.0
41 .5
45.6
47.4
45.0
59.4
59.2
62.2
59.2
6L2
55.3
59-2
58-2
58.4
58.2
60.7
54.3
57.0
60*5
59.4
60.2
60.2
57.2
54.0
57.0
REGEN.
S OUT X
OF FED
44*6
46*0
40.0
55. 1
56.2
56.9
51.9
57.2
51.3
56.9
52.5
53.4
53.3
39.0
61.3
60*6
47.3
54.9
52.3
49.5
63*8
66*5
70.0
67.3
70.5
58.5
66*4
66.2
66.7
63-3
68.2
59.5
63.3
65.3
62.3
61.7
66.9
63-8
60.2
62.8
- 311 -
-------
RUN 6:
APPENDIX C: TABLE IV.
DESULPHURISATION PERFORMANCE PAGE 9 OF i2
DAY. HOUR
16.0030
16.0130
16.0230
16*0330
16.0430
16.0530
16*0630
16*0730
16.0830
16.0930
16* 1030
16. 1 130
16. 1230
16.1330
16. M30
16*1530
16* 1630
16. 1 730
16. 1830
16. 1930
16*2030
16.2130
16*2230
16.2330
17.0030
17.0130
17*0230
17.0330
17.0430
17.0530
17.0630
17.0730
17*0830
17*0930
17.1030
17. 1130
SULPHUR GAS
REMOVAL VEL.
% M/S
80.1 1*35
79.7
80.1
78-7
79.0
77.9
77.9
77.7
77.8
76°8
75.8
73.8
73.5
73«4
72.3
74.0
75.0
73.5
73.6
71.6
71 .6
72.2
73.7
73.5
71.9
70.5
69.5
• 39
.38
»38
• 37
.39
• 37
• 38
• 38
• 38
• 43
.45
• 45
.45
.44
.42
• 44
.47
.45
.41
• 44
.36
.40
.40
• 41
.06
• 03
70.6 0.97
71.8 0-94
72o6 0.94
72.7 0.91
76*6 0.86
77.2 1.00
77.1 0.94
77.2 1.45
76.5 1-42
G-BED
DEPTH
CENTIM
57.
57.
55.
57.
57.
57.
57.
57.
55.
55.
55.
55.
55.
55.
53.
52.
49.
45.
45.
41 •
41.
43.
45.
45.
43.
43.
40*
43.
43.
43«
43.
44*
43.
50.
47.
47.
AIR/ CAO/S
FUEL RATIO
% ST. MOL.
20.8 1.32
21.4 1.22
21*4 1.34
22.2 1.23
22.0 0.85
21*0 0.93
21*4 1.46
21.4 1.08
2L3 0.87
21.5 0.84
22.0
22.6
22.7
22.8
22.7
22.1
22.1
22. 1 (
21.8
21.6
21.6
20.8 5
21*3
21 o4
21.3
20*4
20.4
20*1
19.6
20.0
19.8
18.7
21.9
21.1
22.2
22.1
.08
.17
.35
.75
.50
.50
.89
9.86
.21
.82
• 71
?.04
• 61
.36
.36
.20
.02
• 89
.75
.61
.44
.15
.90
.46
.25
.43
X CAS
TO CAO
57.2
59.7
57.1
55.6
55.9
57.0
57.2
56.4
56.9
57-7
53-7
54-4
51 .4
49.3
55.5
48* 1
52.7
50.1
57.0
65.4
46.4
49.8
55.9
50.1
46.4
48-9
42*1
44.7
51 .7
45.7
47. 1
50.0
51.3
53.9
53.7
51 .3
REGEN.
S OUT I
OF FED
63.0
66.6
62.1
61 .1
62.9
63.7
64.2
64.5
64. 7
65.0
60.7
61.3
59.0
56.9
63.5
55.7
59.4
60.2
68.7
84.6
58.6
62.8
71.4
64.2
59.7
61.8
55.2
57.9
66.2
58*8
59.2
63.4
65.0
69.2
67.4
64.8
SHUT DOWN AT 17.1130 FOR 40 HOURS
- 312 -
-------
RUN 6i
APPENDIX
DESULPHURISATION
C* TABLE IV.
PERFORMANCE PAGE 10 OF 12
DAY. HOUR
19.0430
19.0530
19.0630
19.0730
19.0830
19.0930
19. 1030
19.1 130
19.1230
19-1330
19. 1430
19.1530
19. 1630
19.1730
19. 1830
19-1930
19.2030
19.2130
19.2230
19.2330
20.0030
20.0130
20.0230
20.0330
20.0430
20.0530
20*0630
20.0730
20.0830
20.0930
20. 1030
20 . 1 1 30
20.1230
20*1330
20. 1430
20. 1530
20.1630
20*1730
20.1830
20.1930
SULPHUR GAS
REMOVAL VEL.
% M/S
87.7
84. 1
80.6
78.4
75.7
73.7
73.3
74.1
75.2
75.3
75.2
77.5
65.2
79.8
82.0
80.9
78.1
8L3
78.5
75.0
78.0
78.0
76.7
78-7
77.7
.35
.39
• 39
.41
• 35
• 30
• 41
• 39
.37
.35
• 38
• 37
• 36
.41
• 35
.36
• 39
.35
.38
.35
.36
.36
• 36
• 34
.34
77.4 1-36
74.0 1.34
74.6 1.36
76.4 .33
77.0 .31
76.4 .29
75.8 .32
67.8 .26
.26
.27
• 24
76.8 .31
78-7 .34
80.3 .38
80.5 .36
G-BED
DEPTH
CENTIM
40.
40.
41 .
41 •
38.
38.
39.
39.
41 .
45.
40.
36.
40.
40*
40.
44*
43.
44.
45.
44*
44.
44*
44.
44*
43.
43.
41 •
43.
43*
43*
44*
44*
45.
48.
48.
48*
48.
48.
48.
48*
AIR/ CAO/S
FUEL RATIO
X ST. MOL.
20.6
20.6
21.3
20.8
20.6
19.2
21.0
20.7
20.7
20.4
21 .0
21.0
21 .6
21 .0
20.1
21 .3
21.1
20.6
20.6
20.6
20.7
21.1
.73
.02
.24
.24
.09
.09
.26
• 21
.21
.30
.29
• 11
.21
• 24
.05
9.98
.40
.32
.07
.26
.02
.00
20*4 0*86
19.7 0.88
19.5 1.02
20.0 1.16
20.5 0.88
20*9 0.84
20.9 1*66
20.2 1-12
19.7 0.84
20*5 0.84
20.1 L19
19.9 1.12
19*9 0*67
19*3 0.63
20.4 1*26
20.4 1.57
22*2 1*61
21 .6 1 .81
X CAS
TO CAO
49.7
58-5
58.6
56.0
56.0
54.7
56.3
61.5
61*3
66*7
70.5
68.6
57.9
56.1
67. 1
65.4
38.9
79.0
69.2
71 .0
65. 1
71.1
73.3
60*0
71.2
70.2
63*6
63*4
67.1
53.3
60.6
71 .8
69.9
78.1
67.7
60.5
55.4
63.3
57.4
62*1
REGEN.
S OUT X
OF FED
•
58*6
70.0
68. 1
67.8
66.0
63. 1
65.9
67.9
67.2
69.9
75.8
80.7
69.2
62.8
74* 1
66*4
19.9
73.9
66.6
72.0
72.4
84. 1
79-5
72*6
80-7
83.9
79.8
78.0
74.7
63*6
72.4
81.5
79.6
79.0
75.6
68.8
63*6
89.1
82.7
77.1
- 313 -
-------
RUN 6:
APPENDIX C: TABLE IV-
DESULPHURISATION PERFORMANCE PAGE H OF
DAY. HOUR
20*2030
20*2130
20.2230
20.2330
21 .0030
21.0130
21.0230
21 .0330
21.0430
21.0530
21 .0630
21.0730
21 .0830
21 .0930
21.1030
21. 11 30
21 .1230
21. 1330
21.1430
21 . 1530
21*1630
21.1730
21.1830
21 .1930
21.2030
21.2130
21 .2230
21*2330
22.0030
22.0130
22.0230
22.0330
22.0430
22.0530
22.0630
22.0730
22.0830
22.0930
22.1030
SULPHUR GAS
REMOVAL VEL.
X M/S
80.3
80.7
80.7
79.8
79.7
79.6
79.1
78.7
79.3
79.2
76.3
73.9
72.1
71.7
73.6
74.4
74.9
75.8
75.1
73.7
73.5
74*0
72.7
72.1
72.9
75.6
74.2
73.4
72.4
68.5
69. 1
70.6
71.9
76.2
72.6
76.2
72.0
70.9
71.4
.37
.39
• 43
.40
.42
.41
• 39
.42
.44
.45
.46
.44
• 37
• 40
.38
.36
• 38
• 38
• 38
• 37
.36
• 35
• 36
• 34
• 37
• 36
.40
• 40
• 45
• 38
.41
.41
• 38
• 39
• 39
• 39
.40
• 34
.33
G-BED
DEPTH
CENTI
55.
55.
43.
48.
48.
56.
53.
53.
.50.
STONE
53.
50.
48.
45.
50.
50.
50.
48.
48.
45*
48.
48.
48*
50.
50.
49.
49.
46*
47.
49.
48*
45.
48*
47.
43-
45.
45*
45*
43.
45.
AIR/ CAO/S
FUEL RATIO
M X ST. MOL.
21.7 .27
21*4 .07
23*2 .46
22.3 .43
22*1 .00
22*2 .55
21.3 .69
21.4 .03
22.3 .43
CHANGE
21.5 1.00
21.5 0.
21.7 0.
19.6 0.
20*9 0*97
21 *4
21*1
21*5 f
21.8
2L6
20.7 C
20.2
20*0
20.3
20*2
20.6
20.5
21.2
21*2
21.3
20.4
21.4
21*2
20.6
20.2
20.4
20.5
20*9
• 07
.06
5.89
• 37
• 29
9.56
• 10
• 20
• 34
• 28
• 78
• 10
.30
• 20
• 17
* 14
• 31
• 27
• 22
• 06
• 01
• 1 1
• 14
19.1 0.97
19.2 0.90
X CAS
TO CAO
70*2
62.2
68*8
61 *8
71*5
63.7
58.9
52.8
68.5
72*5
62.7
56.2
57.8
58-2
56.9
57.9
55.9
49.1
54.5
51*8
52.4
52.8
51.9
42*8
58.3
57.0
53.4
57.5
51.2
54*4
55.2
53*6
51.4
45*4
47.0
40*4
50-1
52.7
39.7
REGEN.
5 OUT x
OF FED
63.4
70.9
64* 1
63. 1
80.9
66*8
74.3
58.2
86. 1
87.9
78.3
66.0
57.7
60.3
66.2
60.2
58.6
49.2
62.7
59.1
59.5
60.1
63.1
50.8
61.4
55.4
54.0
62.5
52.6
51.3
59.9
52.5
53*6
51*0
52.8
44.5
56-5
60.1
43*4
- 314 -
-------
RUN 6:
APPENDIX
DESULPHURISATION
C* TABLE IV.
PERFORMANCE PAGE 12 OF 12
DAY.HOUR
22.1130
22.1230
22.1330
22.1430
22.1530
22.1630
22.1730
SULPHUR GAS
REMOVAL VEL.
Z
M/S
G-BED
DEPTH
CENTIM
AIR/
FUEL
*
ST.
CAO/S
RATIO 2 CAS
MOL.
TO
CAO
REGEN.
S OUT X
OF
FED
72.0
71.2
67.3
66.5
64.8
64.2
64.6
.36
• 37
• 30
.32
.36
• 42
.43
43.
42.
42*
42.
43.
53.
46.
20.0
20.1
18.9
18.9
19*0
21.2
21 .4
0.33
0.
0.
0.
0.73
1*01
1.19
54.0
52.1
52.4
54* 1
46. S
49.2
36.5
51.5
44*3
52.6
51*2
51.7
49.3
39.7
" 315 -
-------
APPENDIX C: TABLE V.
RUN 6: GAS COMPOSITIONS
PAGE 1 OF 7
CJ
DAY.HOUR
1 •
1 .
2*
2*
2.
2-
2.
2.
2.
2.
2.
2.
2.
2.
2.
2.
2.
2.
2.
2.
2.
2.
2
2
2
2
3
3
2230
2330
0030
0130
0230
0330
0430
0530
0630
0730
0830
0930
1030
1130
1230
1330
1430
1530
1630
1730
1830
1930
2030
2130
2230
2330
0030
0130
F L
02
Z
4.5
3-5
3*0
3.0
2.2
2.2
2. 1
3.0
2.5
2.9
2.9
2.0
2.0
2.5
2.0
2.0
1.8
1 .8
1 .6
1 .7
2.0
2.1
2.0
2.0
2.0
2.3
2.9
2.5
U E GAS
C02 VOL Z
ANAL
13.0
13-5
13.5
13.5
14.4
14.4
14.4
13.5
14.1
14.1
14. 1
14.1
14.4
13.5
14.4
14*1
14. 1
14.4
14.4
14.4
14.4
14.4
14.4
14.4
14.4
14. 1
13.5
14. 1
CALC
12*4
13*1
13.5
13.5
14.1
14.1
14.2
13.5
13.9
13*6
13.6
14.3
14.3
13.9
14.3
14.3
14*4
14.4
14.5
14.5
14-3
14.2
14.3
14-3
1 4.3
1 4*0
13.6
13-9
S02
PPM
91 •
192.
223*
238.
278.
278.
238.
268.
293.
301.
332.
354.
354.
364*
369.
374.
384.
384.
379.
374.
354.
329.
319.
334.
314.
293.
288.
288.
REGENERATOR GAS
02
Z
12*00
3.00
0.60
1 .80
0.90
0.30
0.40
0 . 40
0.50
0.50
0.50
0.50
0*50
0*50
0*50
0.20
0.20
0.20
0.20
0.20
0.
0.
0*
0.
0*
0*
0.20
0.5?0
C02
Z
0.4
1 .7
2-2
0.6
3.3
2.2
2*3
3.3
4.7
4*4
4.6
5.9
3.8
3*0
5.2
6*8
8.8
7.5
6*4
7.2
4.5
5.0
3-1
3.5
3.9
3-3
2.9
2.6
SO 2
Z
0*
0.
3.9
7.0
7*4
9*4
9*4
8.6
9*0
8.6
8*6
7.4
9*0
7.4
7*2
7*4
6*2
7*0
6.8
6.6
7.6
7.0
7.6
7.6
5.6
8.0
7.4
7*4
GASIFIER
02 VOL Z
ANAL
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
7*0
5*5
5*5
6*0
6.5
6.5
6.5
7.0
6*8
6.8
6.5
7.6
6*8
6*8
6*8
6*6
6.6
6.6
6.6
6*6
7.0
7.2
7.2
7.2
7.2
7.2
7.5
7.3
CALC
17*5
16.9
16.7
16.7
16.6
16.5
16.2
16.5
16.7
16.8
17.0
16.8
17*4
16*8
16*9
16*8
16*5
16*6
16*7
16*8
17*1
17*4
17.3
17. 1
17. 1
17*2
17*2
17. PI
INLET
C02
ANAL
2*76
3*27
2-28
3.27
3*54
3*45
3*45
3*10
3*10
3* 10
3*82
3* 10
3.01
2.93
2.93
3.01
2.93
2.93
2.93
2-93
2.68
2.52
2.60
2.44
2.44
2.44
2.36
2. 44
GAS
VOL Z
CALC
2.79
3*20
3.20
3.20
3*37
3*47
3.62
3.4!
3*24
3-24
3.09
3.09
2*70
3*09
3.09
3.08
3-30
3-31
3. 15
3.09
2*98
2*77
2*82
2*93
2*93
2*87
2*82
3»04
-------
I
00
I-1
-J
3.0230
3.0330 i
3.0430 I
3*0530 J
3*0630 £
3.0730 £
3*0830 2
3.0930 2
3.1030 2
3.1130
3.1230
3.1330
3.1430
3.1530
3*1630
3.1730
3.1830
3. 1930
3*2030
3*2130
3*2230
3*2330
4*0030 !
4*0130 ;
4.0230
4.0330
4.0430
4*0530
4*0630
4*0730
4*0830
4*0930
4*1030
4*1 130
4*1230
4*1330
2*5
?.5
?*5
>*5
>*5
?*3
»•!
S0
>.0
.9
.9
.7
.7
.5
.7
• 5
.5
• 6
.5
.7
• 8
.9
2*0
2*0
1.7
1*8
1*5
2*6
4*8
3*5
4*0
4*0
1.0
1 *4
1-0
1*0
13*8
14*1
13*8
13*8
14. I
14*4
14*4
14*4
14.4
14.4
14*4
14.4
14.4
13*8
13-2
13.8
13*8
13*5
13.8
14*1
13*8
13.8
13*8
13*5
13*8
13*8
13*8
13*0
1 1-7
12*4
12*2
12*2
14*1
14.1
14* 1
14*1
13*9
13*9
13.9
13.9
13-9
14.0
14.2
14.3
14.3
14*3
14*4
14.5
14.5
14.7
14.5
14.7
14.7
14.6
14.7
14.5
14.4
14.4
14*3
14.3
14*5
14.5
14*7
13*9
12*2
13*2
12*8
12*8
15*1
14*8
15*0
15*0
283*
283.
278.
283.
273*
268.
283*
293*
293*
304.
319.
324*
304*
283.
278.
268.
283.
268.
253.
248.
243*
238.
223.
228.
253.
333.
384.
339*
278.
303*
333*
353*
450*
495*
496-
529*
0.50
0.70
0.20
0. 10
0.20
0.20
0.30
0.20
0.
0.
0.
0.
0.
0.
0.
0.
0. 10
0. 10
0.
0.10
0.10
0.20
0*10
0*10
0*30
0.20
0.20
0*20
0*50
0.30
0.20
0*20
0*40
0.50
0*80
0*80
4*1
3*1
2.4
1.7
1 *6
3. 1
2.3
2.6
3.5
3-3
3-5
3.1
5-2
3-5
3.7
4. 1
3.9
3*0
3.7
4.3
5.0
2.5
3.3
8.5
4. 1
1 .3
3.0
3.5
2.4
3.4
3.7
3.9
3-7
3*9
a. 5
4.3
7.0
6.4
7.2
7.4 ]
7*8 1
6.8 1
7.0 1
7.2 1
6-8 1
7.2 1
7.6 1
7.0 1
7.4 1
7.6 1
8.2 1
8.2 1
8.6 1
7.8 1
8*6 ]
8.6 1
8.8 1
8*4 1
8.6
7.8
8.0
7.8 S
8.2
8.8
6.8
7.6
8*2
7.8
7.0
7.4
6*4 ]
6*4 1
17*4
17.4
17.5
8-0
7*5
7*6
7*6
7*8
7*8
7.6
7.6
7.6
7.6
7.8
7.8
7.8
7.8
7.8
7.8
8.0
18.0
18. 1
8. 1
8.1
7.8
>0.0
7.0
7.8
7.8
7.5
7.6
7.6
7.3
6.8
15.5
5.5
17*0
17.0
17*0
17.3
17.1
17.1
17.2
17.6
17.6
17.6
17.7
17.8
17.8
18.1
17.9
17.9
17.9
17.9
17.9
18*2
18.1
18*1
18.1
18.1
15.6
20.0
17.5
17.8
18.1
17.8
17.9
17.9
17.1
17.1
15.7
15.9
2.44
2.44
2-36
2*20
2*28
2*28
2*28
2*28
2*20
2*20
2*12
2*12
2*12
2*28
2*20
2*20
2*20
2*20
2.12
1*96
1*96
1*96
1 .96
1.96
2.12
0.34
2.76
2.20
2. 12
2.28
2.20
2* 12
2*44
2.36
3*01
3*10
2*98
3*04
2*98
2*79
2*94
3*00
2*90
2*55
2*55
2*55
2*51
2*35
2*36
2*06
2*13
2*22
2* 19
2*17
2*22
2*07
2*08
2*09
2.10
2.06
3*88
0.72
2.51
2.25
2.07
2.28
2-23
2.25
2.76
2.80
3.72
3.62
-------
APPENDIX C: TABLE V.
RUN 6: GAS COMPOSITIONS
PAGE 2 OF 7
CJ
M
00
I
DAY.HOUR
4.1430
4.1530
4.1630
4.1730
4.1830
4.1930
4.2030
4.2130
4.2230
4.2330
5.0030
5.0130
5.0230
5.0330
5.0430
5.0530
5.0630
5.0730
0830
0930
1030
1 130
5.1230
5.1330
5.1430
5.1530
5.1630
5«173P»
F L
02
I
1*0
1.0
1.5
2.2
2.5
2.2
2.8
3.5
2.5
2.2
2.2
2.2
2.5
2.2
2.5
2.5
2.1
2.0
2.0
2.0
1 .6
1.8
2.2
1.5
2.5
2.0
2.1
1 .9
U E GAS
C02 VOL %
ANAL
14. 1
13.8
13.8
13.5
13*0
13-5
13.2
12.7
13.2
13.5
13.2
13.5
13.2
13-2
13-2
13.2
13.2
13.2
13.5
13.5
13.8
13.8
13.5
14. 1
13.2
13-8
13. R
14. 1
CALC
15.0
15.1
14.7
14.2
13.9
14. 1
13.7
13.2
13.9
14. 1
14. 1
14- 1
13.9
14.2
14.0
14.0
14.3
14.4
14.3
14.3
14.6
1 4.4
14.1
14. 7
13.9
14.3
14.2
14.3
S02
PPM
494.
494.
425.
362-
359.
306.
£53-
217.
187.
167.
172.
182.
206.
216.
241 •
290.
203.
206.
205.
208.
193-
194.
196.
176.
169.
177.
182-
178.
REGENERATOR GAS
02 C02 S02
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
01 .
0.
0.
0.
0.
0.
0.
0.
0.
0.
1 .
%
50
50
50
50
50
50
50
40
70
40
30
.40
30
50
40
30
40
40
40
20
20
00
1.00
0.
0.
0.
0.
0.
50
30
40
40
50
%
4.5
3. 1
2.8
3.5
3.9
3.6
3.7
2.3
2-8
2-3
4.3
2.6
3.9
2.5
2.0
2.5
3.4
3.5
3.9
4.3
5.5
5.0
2.0
2.8
6.2
3-7
4.2
4-0
%
7.0
7.4
7.0
7.4
7.4
7.8
7.2
7.4
6.8
6.6
8-2
7.8
5.4
8.2
8-6
6.8
6.2
7.2
8.2
7.8
8.2
7.8
6-2
7.6
7.4
7.4
7.0
7. PI
GASIFIER
02 VOL %
ANAL
15.5
15.8
15-8
1 6.0
16.2
16.4
16.5
16.5
16.8
16.8
17.0
17.0
17.0
17.0
17.0
17.0
17.0
16.9
16.8
16.6
15.5
1 5.5
15.5
1 6.5
16-3
16.0
16.2
16.2
CALC
16.2
17.5
17.4
17.6
17.6
17.4
17.6
17.9
17.6
17.5
17.5
17.3
17.4
17.3
17.5
17.7
17.4
17.0
17.2
17. 1
17.4
17.5
17.6
17.4
17.5
17.4
17.4
17.3
INLET
C02
ANAL
3*01
2.28
2.28
2.28
2. 12
2. 12
2.36
2-28
3.63
2.12
1 .96
2.04
1.96
1.88
2.20
2-36
2.52
2.44
2-20
1.96
2.36
2.28
2.28
2.28
2.20
2.?8
2.28
2-2F
GAS
VOL %
CALC
3.41
2.44
2.51
2.46
2.35
2.62
2.47
2.24
2.43
2-53
2.46
2.64
2.58
2.58
2.51
2.39
2.51
2.81
2.68
2.77
2.59
2.52
2.47
2.60
2.53
2-64
2.65
2.73
-------
I
U)
M
vo
I
5. 1830
5. 1930
5.2030
5-2130
5.2230
5.2330
6.0030
6.0130
6.0230
6.0330
6*0430
6.0530
6.0630
6.0730
6*0830
6 . 09 30
6*1030
6.1130
6.1230
6.1330
6.1430
6.1530
6« 1630
6.1730
6 . 1 8 30
6 . 1 9 30
6.2030
6.2130
6.2230
6.2330
7.0030
7.0130
7.0230
7.0330
7.0430
7.0530
2.2
2.8
2.1
2.0
2.5
2.0
2.0
2.2
2.2
2.2
2.3
2.2
3.2
2.5
2.2
1 .9
2.1
3*0
2*0
1.8
3.0
2.0
1.9
2.0
2.0
1 .9
2.4
2. 1
2.2
2.3
2.5
2.2
2.4
2-4
2.8
13.8
13.5
13.8
13.5
13.5
13.8
13.5
13.2
13.2
13-5
13.5
13.2
12.7
13-2
13.5
13.8
T3.5
12.7
13.5
13.8
13.0
13.5
13.8
13-5
13.5
13.8
13.5
13-5
13.5
13.5
13.2
13.5
13.2
13-5
13.2
14.1
13-7
14.2
14.3
13-9
14.3
14.3
14.1
14.1
14-1
14.0
14.1
13.4
13.9
14.1
14.3
14.2
13.5
14*3
14.4
13.5
14.3
14.3
14.3
14.3
14.4
MI
14.0
14.2
14.1
14.0
13.9
14. 1
14.0
14.0
13.7
187.
-
404*
354.
371.
364.
326.
324.
390.
376.
388.
338.
325.
354.
342.
334.
324.
31 1.
306*
322*
303*
304.
318.
324.
3!S.
331.
0.50
0.40
0.40
0.50
0.60
0.70
0.60
0.60
0.50
0.50
0.60
0.50
0.60
0.50
0.60
0.60
0.50
0.30
0.50
0.60
0.40
0.30
0*30
0.30
0-20
0.80
4.1
4.4
4.5
4.7
4.5
4.3
4.7
4.4
4.2
4*4
4.4
4.4
4.0
3.8
4.1
4.2
4.4
5.4
4.3
6.4
4.7
5*0
7.5
5.0
4-3
4.1
7.4
7.0
6.8
8.4
7.0
7.0
7.4
7.2
7.0
7.2
7.0
7.0
7.2
7.2
7.2
7.2
7.2
7.0
7.0
6*6
6.2
6*6
5.8
7.4
7.4
7.4
16.0
16.0
15.9
15.9
15-9
15.9
15.8
16.0
15.9
15.9
16.0
16.0
16.1
16.2
16.8
17.6
17.6
17.9
17.4
17.6
17.8
17.7
17.7
17.7
18.1
18.1
17.4
17.5
17.3
17.3
17.3
17.2
17.2
17.3
17.3
17.3
17.2
17.3
17.7
17.5
17.5
17.5
17.6
17.8
17*9
17*8
17*9
17.7
17.7
17.7
18.1
18.1
SSED DATA READING
313.
317.
324.
298.
286.
273.
303.
324.
305-
0*60
0.25
0.25
0.25
0.25
0.25
0.?0
0. 15
0.15
4.2
4.0
5.5
5.2
3.9
5-3
3.6
4.5
2.9
7.0
7.0
5.0
6.8
7.6
8.6
9.0
8.8
7.8
18. 1
18*2
17.6
18*0
18.2
17.9
18.0
18. 1
18*0
18. 1
18.2
17.5
17.6
18.2
17.7
17.7
18. 1
18.0
2.28
2.28
2.36
2*44
2*36
2.28
2.28
2.20
2.28
2*28
2.20
2.20
2.04
2. 12
2*12
2.12
2.12
1 .96
2.20
2*12
2-12
2*12
2*20
2*12
2.04
2-12
2.04
2-20
2.36
2.20
1.96
2.20
2.12
2.04
2.04
2.63
2.62
2.68
2.61
2.67
2.78
2.67
2.61
2.57
2.65
2. 72
2-57
2.39
2.49
2.51
2.56
2.41
2.24
2.23
2.28
2.20
2.33
2.37
2.33
2.06
2.09
2. 1 1
2.00
2.49
2.48
2.00
2.36
2. 31
2. 1 1
2.20
-------
APPENDIX Cr TABLE V-
RUN 6: GAS COMPOSITIONS
u>
10
O
DAY.HOUR
7.0630
7.0730
7.0830
7.0930
7.1030
7.1130
7.1230
7.1330
7.1430
7.1530
1630
1730
1830
1930
2030
7.
7.
7,
7.
7,
7.2130
7.
7.
8.
8.
8.
8.
8.
8.
8.
2230
2330
0(930
0130
0230
0330
0430
0530
0630
8.0730
8.0830
8.0930
F L
02
%
2.2
2.2
2.3
2.5
2.8
2.2
2.6
2.6
2.7
2.2
2.0
2.2
1.9
2.1
2.3
2.4
2.3
1.8
1 .9
2.5
2.5
2.3
2.6
2.3
2.4
2.6
2.3
2.3
U E GAS
CO2 VOL X
ANAL
13.5
13.5
13.5
1-3-2
13.2
IS. 5
13.2
13.2
13.5
13.5
13.5
13.2
13.8
13.8
13.0
13.2
13.2
13.8
13-5
13.2
13-2
13.5
13-2
13.2
13.2
13.2
13.2
13.2
CALC
14.1
14-1
14.0
13.9
13.7
14.1
13.9
13.8
13-8
14*2
14.3
14*1
14.4
14.2
14. 1
14.0
14.1
14.5
14.4
13-9
13.9
14.1
13.8
14. 1
14.0
13.8
14. 1
14. 1
SX32
PPM
286*
279.
263.
255.
243.
243.
266.
281.
298.
292.
312.
321-
324.
283.
303.
334.
364.
392.
384.
388.
354.
346.
374.
374.
399.
409.
420.
445.
REGENERATOR GA
02 COS S02
*
0.15
0. 10
0. 10
0.10
0.10
0.20
0.20
0.30
0.30
0.30
0.20
0.20
0.20
0.20
0.30
0.30
0.40
0*30
0.30
0.30
0.25
0.30
0.30
0.30
0.20
0.30
0.30
0.30
*
4.1
4.6
3-6
4.5
4.9
4.5
4. 1
5.3
4-3
4-9
5.1
5.1
5.2
4.3
4. 1
4.5
4*0
6.0
5-7
4.7
6.2
4.1
4. 1
4.3
4.3
3.8
3.7
•4-3
X
8.0
8.4
8.6
9.0
9.0
8.8
9.0
8*0
8.6
8.2
8.2
8.2
8.0
8.2
8.2
7.8
8.0
8.2
8.6
8.6
8.2
8.6
9.0
9.2
9.0
9.0
9.2
9. PI
PAGE 3 OF 7
GASIFIER INLET GAS
02 VOL X C02 VOL X
ANAL CALC ANAL CALC
17.9
18.0
18.0
17.8
17.8
17.2
17.4
17.5
17.4
17.5
17.4
17.5
17.6
17.6
17.6
17.6
17.4
17. 1
17. 1
16.3
16.3
16.3
16.5
16.6
1 6.6
16.6
16.7
16.6
17.6
17.7
17.4
17.8
17.8
17.6
17.6
17.7
17.7
17.5
17.6
17.6
17.5
17.6
17.6
17.7
17.7
17.6
17-6
17.0
16.7
16.7
17.0
17.0
17.0
17.1
17. 1
17.?
2.12
2.04
2.12
2.12
1.96
2.12
1.96
2.04
2.04
2.04
2.04
2.04
2.12
2. 12
2. 12
2.04
2. 12
2.44
2.44
2.84
3.01
2.93
2.84
2.84
2.84
2.84
2.76
2.84
2.42
2*40
2«59
2.30
2-36
2.47
2.42
2.35
2.43
2.50
2.45
2.40
2.50
2.50
2.35
2.35
2*31
2.45
2.39
2.87
3.04
3. 10
2.S7
2.82
2.78
?>.75
2.66
-------
to
8. 1030
8.1130
8.1230
8. 1330
8. 1430
8. 1530
8. 1630
8. 1730
8. 1830
8« 1930
8.2030
8.2130
8.2230
8.2330
9.0030
9.0130
9.0230
9.0330
9.0430
9.0530
9.0630
9.0730
9.0830
9.0930
9.1030
9. 11 30
9-1230
9.1330
9-1430
9. 1530
9. 1630
9.1730
9. 1830
9.1930
9.2030
9.2130
2.2
2.1
2.2
2.2
2.5
2.3
2.3
3.8
3. 1
2.9
3.0
3.1
3.5
3.4
3.5
3.5
3-5
3.3
3.5
3-5
3.5
3.4
3-4
1.2
1.0
0.9
2.2
2.0
1 .9
1.5
1 .7
2.0
2.4
2.5
2.2
2.4
13.5
13.5
13-2
13.2
13.2
13.5
13.2
12.7
13.0
13.2
13.2
13.0
13.0
12-7
12.7
12.7
12.7
13.0
12.7
12.7
12.7
12.7
13.0
14.4
14.4
14.4
13.5
13-5
13.8
13.8
13.8
13.8
13-5
13-2
13.2
13.2
14. 1
14.2
14.1
14.1
13.9
14.1
14.1
12.9
13.5
13.6
13-5
13.5
13.1
13.2
13.2
13.1
13.1
13.3
13.1
13.1
13*2
13.2
13-2
14.9
15.0
15-1
14.1
14.2
14.3
14.6
14.5
14.3
14.0
13.9
14.2
13-9
435.
438.
425.
425.
418-
423.
445*
429.
406*
379.
377.
379.
374.
361*
369.
401.
398.
394.
402*
470.
467.
473.
475-
455.
452.
453.
407.
376.
354.
354.
421.
409.
354.
326.
312.
450.
0.30
0.30
0.30
0.20
0.20
0.40
0.40
0.40
0.40
0.40
0.40
0.40
0.50
0.40
0. 40
0.40
0.40
0.40
0.40
0.40
0.40
0.50
0.50
0.50
0»50
0*40
0.30
0. 10
0.20
0.20
0.20
0. 10
0. 10
0. 10
0. 10
0.20
5.0
4.5
4.9
5.7
5.2
5.8
5.5
4.7
6*0
5.9
6.0
6.3
5-3
5-2
4.4
4.3
5.3
5.5
5.3
3.4
3.6
3.5
3-7
4.3
4.9
4.2
4.6
6.4
5.8
6.4
5.2
5.4
5.7
5.0
4.2
3.7
8.8
8.6
8*6
8.4
8.2
7.8
8.0
7.8
7.4
7.8
7.8
8.0
7.8
7.8
7.4
7.2
7.4
7.2
7.4
7.4
7.2
6.8
6.6
6.4
6.6
6.6
7.4
7.8
7.6
7.6
8.2
8.2
7.4
7.4
7.8
7.2
16.7
16*6
16.6
16.6
16.7
16.7
16.7
16.3
17. 1
17. 1
17.3
17.0
17.2
17.2
17.2
16.6
16.6
16.5
16.6
16.6
16.6
16.6
16*6
16.1
16.1
16.1
16.3
16.5
16.5
16.5
16.5
16.6
16.6
16.6
16.6
16.2
17.2
17.1
17. 1
17. 1
17. 1
17.3
17.4
16.7
17.5
17.3
17.5
17.4
17.4
17.6
17.4
17. 1
16*8
17.0
17.1
16-5
17.1
17.0
17.0
16*6
16.8
16.2
16.6
16.8
16.8
16-7
16-7
17.0
17.0
17. 1
16-9
16*6
2.93
2.93
2.93
2.93
2.84
2.93
2.84
3.36
2.76
2.76
2.60
2-84
2.76
2.76
2.93
3.27
3.27
3-36
3*36
3*27
3.45
3-45
3-54
3-82
3.82
3-82
3.54
3.45
3.45
3.45
3-54
3.27
3.27
3. 18
3.27
3.73
2.71
2.76
2.76
2.76
2.76
2.65
2-55
3. 17
2.51
2.68
2-59
2.59
2-69
2.42
2.59
2.86
3.01
2.92
2*86
3-26
2*86
2.86
2.92
3.17
2.99
3-42
3. 15
2.99
3.05
3.05
3.05
2.88
2.88
2-77
2.87
3. 12
-------
RUN
APPENDIX C:
6: GAS
TABLE V.
COMPOSITIONS
DAY.HOUR
9-2230
FLUE GAS
02 C02 VOL X S02
X ANAL CALC PPM
REGENERATOR GAS
02 C02 S02
XIX
2.4 13.5 13.9 424. 0.20 3.5
SHUT DOWN AT 9-2230 FOR 23 HOURS
6.4
PAGE 4 OF 7
GASIFIER INLET GAS
02 VOL X CO2 VOL X
ANAL CALC ANAL CALC
16.2 16.4 3.73 3.34
1
u>
10
10
1
0*2130
0.2230
0.2330
• 0030
• 0130
• 0230
• 0330
• 0430
• 0530 '<
• 0630
• 0730
• 0830
• 0930
• 1030
• 1130
• 1230
• 1330
• 1430
•1530 Z
• 1630
• 1730
.1830
• 1930
•2030 J
.2130 £
•2230 J
• 9 13«5 14.4 429. 0-80 0.6 4«8 21-2 2L2 0.02-0.14
•3 14.1 14.8 395* 0*60 2-4 7.0 17.4 16*9 3*18 2*91
•0 14.1 15.0 375* 0.20 3.5 7.8 17.0 16-6 3-36 3*10
•3 13.8 14.8 367. 0.20 3.3 7.6 17.0 17.0 3.18 2.82
.4 14.1 14.7 351* 0«40 2*6 6*2 17.0 17-0 3«27 2.89
•4 13-8 14.7 324. 0.20 3.1 7.4 17.0 17.0 3.10 2.83
•4 13.8 14.7 294. 0.40 3-1 7.2 17.1 17.2 3»01 2.70
.5 13.8 14.6 293. 0«20 3«5 7.6 17-2 17.2 2.93 2.70
>.0 13.5 14.3 273- 0.10 3-4 7.6 17.2 17.3 2.76 2.64
•3 13-8 14.8 263. 0.20 3.0 7.4 17.4 17.1 2.76 2.73
.8 13.8 14.4 247. 0.20 2.2 7.4 17.3 17.2 2-68 2.71
• 8 13^.8 14.4 227. 0.20 2.8 7.0 17.4 17-3 2.44 2.69
•2 14. 14.8 229. 0.20 3« 1 6-8 17.6 17.4 2»52 2.59
.1 14. 14.9 244. 0.30 3-5 5.8 17.5 17.2 2.44 2.66
.0 14. 15-0 273. 0-20 3-1 6-8 17.7 17.5 2.36 2.43
•2 14. 14.8 269. 0.25 3.6 6-8 17.6 17.3 2.36 2.61
•2 14. 14.9 253- 0.25 3«9 5-8 17.8 17.8 2.36 2.24
.7 13.8 14.5 233. 0.25 2-6 6.2 17.0 17.1 2.76 2.76
>.0 13.5 14.2 211- 0.30 1.9 6.0 16.8 17.1 2.93 2.74
.9 13.5 14.3 213- 0.30 3-1 7-4 16.9 17.0 2.84 2.80
.5 13-5 14-6 218. 0-20 3.0 7.0 16.9 17.0 2.76 2.75
.7 13.8 14.5 233. 0.20 1.5 7.8 16.9 17-1 2.76 2.81
.9 13.5 14.3 260. 0.15 1-6 8.8 16.7 17-1 2.84 2.76
?.0 13«2 14.3 256. 0.15 3« 1 8.2 16«R 17.2 2.76 2.61
>.0 13. 5 14. 3 286. 0.30 1-9 7.4 16. 4 17.0 3 • 27 P.. 87
>.0 13.8 14.2 279. 0.10 3.5 7.0 15.5 16-5 3-9P 3.P3
-------
1 1 .2330
1 2*0030
12.0130
12.0230
12.0330
12.0430
12.0530
12*0630
12*0730
12.0830
12.0930
12.1030
12. 1 1 30
12. 1230
12.1330
12.1430
12.1530
' 12.1630
w 1 2 . 1 7 30
£ 12.1830
12.1930
12.2030
12.2130
12.2230
12.2330
13.0030
13.0130
13.0230
13.0330
13.0430
13.0530
13-0630
1 3-0730
2.4
2.8
2.2
2.5
2.5
2.9
2.9
2.9
2.3
2.0
2.0
2. 1
2.2
2-2
2-2
2. 1
2.0
2.0
1.5
2.0
1.9
2.2
2.2
2.3
2.6
3.0
2-5
2-3
3.0
3.0
2.9
2.8
3.0
13.5
13-0
13-1
13.2
13.2
12.7
12.7
13.0
13.5
13.8
13.8
13.5
13-5
13.8
13.5
13.5
13.5
13.5
13*8
13.2
13.8
13.5
13-2
13«2
13-0
13.0
13.2
13-5
13.0
13.0
13.0
13-2
13*2
13.9
13.6
14* 1
13-9
13.9
13.6
13.6
13.6
14.0
14.2
14.2
14.2
14. 1
14. 1
14* 1
14.2
14.2
1 4.2
14.6
14.2
14.3
14.1
14.1
14.0
13.8
13.5
13.9
14.0
13.5
13-5
13.5
13-6
13.4
243.
223-
216.
216.
263.
278.
260.
228.
203-
207.
203.
220.
228.
234.
241 .
221-
215.
220.
243.
261 •
276.
271.
263.
243.
236.
233.
279.
284.
256.
243.
250.
256-
237.
0.10
0. 10
0.30
0.20
0.20
0.25
0.25
0.25
0.25
0.25
0.50
0.20
0.20
0.20
0.20
0.20
0.30
S-40
0.30
0.20
0.40
0.30
0.30
0.30
0.30
0.20
0.20
0.20
0.20
0.20
0.20
0.20
0.20
3.3
2.2
1.6
1.6
1.7
1.4
1.6
1.6
1.7
1.8
1.3
1.5
2.1
1.7
1.9
1.9
1 .6
2.0
1.6
2.5
1-6
1.6
1-7
1.7
1.6
1 -4
1.9
2.6
3.9
1.5
1.5
2. 1
2. 1
5.4
5.8
6.2
7.0
6.6
6*6
5.4
5.4
6.2
6.2
4*6
7.4
6.6
6.2
6.4
6.2
6*0
4.8
5.8
6.2
5.8
6.4
6.2
6.6
7.0
7.4
5.0
7.0
6.2
6*6
6.6
6.4
6.4
16. 1
16.2
16.6
16.0
16.2
16.3
16.3
16.4
16.5
16.4
16.4
16.7
16-3
16.4
16*4
16.4
16*4
15.7
15-0
15.7
15.6
15.9
15*9
15.8
15.9
15.7
15-5
15.5
15.6
15.6
15-6
15.5
15-5
16*6
16.5
16.8
16.7
16.9
16.9
16.9
16.9
16.6
16*6
16.8
17.3
16.8
17.0
17.0
16.9
16-9
16.4
15.7
16.2
16*3
16.7
16-4
16-3
16.2
16.5
16.4
15.9
16.2
16.1
16.1
16.0
16.3
3.45
3.45
3.01
3.27
3.27
3. 18
3.27
3.27
3.10
3» 10
3. 18
2.76
3. 10
3.01
3.01
3- 10
3. 10
3.45
3-92
3.45
3-63
3-54
3.45
3.54
3.54
3-45
3-82
3.82
3.73
3.63
3.63
3-63
3. 63
3-22
3.20
2-92
3.07
2.96
2.89
2.87
2.92
3. 1 6
3.21
3.08
2.67
3.02
2.90
2.87
2.93
2.93
3.30
3.73
3.36
3.38
3-07
3.25
3.31
3.37
3-25
3.31
3.66
3.47
3.50
3.54
3*64
3-43
-------
APPENDIX C: TABLE V-
RUN 6l GAS COMPOSITIONS
PAGE 5 OF 7
K>
4*.
DAY.HOUR
13.0830
13.0930
13.1030
1 3 • 1 130
13.1230
13.1330
13*1430
13.1530
13.1630
13.1730
13.1830
13*1930
13*
13-
13*
13.
14.
14.
14.
14*
14.
14.
14.
14.
14*
14.
14.
14.
2030
2130
2230
2330
0030
0130
0230
0330
0430
0530
0630
0730
0830
0930
1030
1 130
F L
02
X
2.5
2. 1
2.5
2.2
2.2
2.2
2.0
2.1
1.8
2.1
2.1
2.7
2*4
2.2
2.0
1 .9
1.9
2.0
2.1
2.1
2.2
2.0
2.5
2.2
2.2
2.3
2.0
2.1
U E GAS
C02 VOL X
ANAL
13-5
13.5
13.5
13-5
13-5
13.5
13-5
13.5
13-5
13.8
13-5
13*0
13*0
13.2
13.5
13-5
13.5
13.5
13-2
13-2
13.0
13.2
13.0
13.2
13.2
13-2
13-2
13.5
CALC
13.8
14.1
13.9
14.1
14*1
14*1
14.2
14.2
14.4
14.2
14.2
13.7
13.9
14.1
14.2
14.3
14.3
14.2
14.1
14-2
14. 1
14.2
13.9
14. 1
14. 1
14.0
14.2
14.2
S02
PPM
223-
223.
253.
253.
227.
239.
250.
282.
324.
332.
336.
351.
450.
728.
687.
621.
546.
556.
569.
577.
554.
538.
598.
612.
572.
544.
516.
494.
REGENERATOR GAS
02 C02
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
1.
0.
1 .
1 •
1.
0.
0.
X X
20
40
30
30
25
30
30
20 J
25
15
20
25
20
20
30
.9
• 4
• 4
.6
• 6
.2
.7
».0
.9
.6
.7
• 3
.6
.0
• 0
30 0.8
20 0.8
20 0.8
20 0.6
20 0.6
20 1 .4
20 0.8
50 0.6
20 1 .0
20 0-8
20 1.2
20 0.8
?0 I. PI
S02
X
6-2
4.6
5.6
6*0
6.4
7.0
9.0
8.2
7.6
7.6
7.0
6.6
7.0
5.0
4.2
5.2
5.4
6.2
5.8
5.4
5.8
5.4
5.8
5.4
5-4
5.4
4.8
6.2
GASIFIER
02 VOL X
ANAL
15.9
15.8
15.7
15.7
15.6
15.6
16.0
15.5
15.6
15.8
15.7
15.7
15.6
15.7
15.2
15-0
14-9
14.9
14-9
14.9
14.9
15-2
16.0
15-8
16. 1
15.3
15.3
15-0
CALC
16.2
16.1
16.3
16*2
16*2
16.4
16.5
16.4
16.3
16*4
16.5
16.3
16.4
16.4
16.0
15.9
15.6
15*6
15.7
15.5
15. 1
15.6
16.2
16.8
16.7
16.5
15.8
15.7
INLET
GAS
C02 VOL %
ANAL
3.54
3.63
3.63
3.63
3.63
3.45
3.27
3-45
3-54
3.45
3.54
3.45
3-54
3.45
3.82
3.92
4.02
3.92
3.92
3.92
4.02
3.82
3.45
3.45
3.27
3.63
3.82
3.92
CALC
3.50
3.51
3.46
3.46
3*46
3.27
3. 19
3.25
3.34
3.32
3.19
3.32
3.22
3.24
3.53
3*60
3-84
3.86
3-68
3.84
4.04
3.76
3.36
2-98
3.02
3. 17
3.61
3.77
-------
U)
to.
en
14. 1230
14. 1330
14*1430
14. 1530
14. 1630
14. 1730
14.1830
14.1930
14-2030
14.2130
14.2230
14.2330
15.0030
15.0130
15.0230
15.0330
15.0430
15.0530
15.0630
15.0730
15.0830
15.0930
15.1030
15.1 130
15. 1230
15.1330
15. 1430
15. 1530
15. 1630
15. 1730
15. 1830
15. 1930
15.2030
1 5.2130
15.2230
1 5.2330
2-0
2.0
2.0
2.0
1.8
2.0
1.8
2-0
2.0
2.1
2.1
2.1
2.1
2.0
.9
.2
.4
.3
.4
.2
.0
.0
2.0
2.0
2.0
2.0
2.8
2.2
2.2
2.2
2.0
1 .6
2.4
2.8
2.5
2.2
13.8
13-5
13.5
13.5
13.5
13-5
13-5
13.5
13.5
13.2
13.2
13-2
13.5
13.5
13.8
13.8
13.8
13-8
13.8
14. 1
14* 1
14. 1
13-5
13-5
13-5
13.5
13.5
13.5
13.5
13.8
13-5
13.8
13.5
13.2
13.2
13.5
14.2
14.2
14.2
14.2
14.4
14.2
14*4
14.2
14.2
14.2
14.1
14.2
14.2
14.2
14«3
14*8
14.7
14.8
14.7
14*8
15.0
15.0
14-2
14.2
14.2
14.2
13.6
14-1
14. 1
14.1
14.2
14.5
13-9
13-6
13.9
14.1
492.
496.
475.
504.
514.
506.
528.
506.
512.
496.
483.
473.
546.
586.
552.
541.
432.
398.
363-
312.
316.
355.
346.
299.
281.
270.
269-
269.
269.
269.
264.
250.
277.
286.
283.
288.
0.20
0.10
0.20
0. 10
0* 10
0.10
0.20
0.10
0.
0.50
0.20
0.20
0*50
0.40
0.80
0.60
0.50
0. 10
0.20
0.30
0.30
0.
0.10
0.10
0.10
0.
0.
0.
0.
0.
0.
0.
0.
0.
0. 10
0. 10
1 .0
0.9
1 .0
1 .5
.3
.0
.7
. 1
.0
0.4
0.9
0.8
0.4
0.5
0.3
1 .4
2-3
1.8
1.7
1.3
1.2
2.7
2.2
2.2
2.2
2.5
2-2
2.2
1.9
2.7
2.7
3.0
1.6
1.8
1.6
1 *6
6.2
6.4
5.8
6.4
5.8
6.4
5.8
6.0
6-0
3.9
5.2
5-2
4*4
5-0
5.0
4.2
5.4
6*4
6-8
6.6
6.8
5.6
6.4
6.2
6.2
6.8
7.2
6.4
6.8
7.0
6.8
6.8
7.4
7.0
6.6
7.0
15.0
15.0
14.9
14.9
14.8
14.8
14.8
14.8
14.8
14.8
14*5
14.5
14.8
14.5
14.6
14.7
14.7
14.7
14.7
15.
15.
15.
15.
15.
15.
14.8
14.8
14.8
15.2
15.2
15. 1
15-1
15.1
15.4
15.4
1 5.4
15.7
15.6
15-6
15.9
15.5
15.5
15-4
15.8
16.0
15.8
15-2
15.8
15.8
15.8
15. 1
15.8
16.0
15.8
15.6
16.2
15.9
16.0
16.5
16.0
16.0
16.0
16. 1
16.0
16.0
16.0
16. 1
16.5
16-3
16.4
16. 1
16.4
4.02
3.82
3-82
3.92
4.02
4.02
4.02
4.02
3.82
3.73
4.02
3-82
3.82
3*82
4.21
4.02
3.92
3-92
3.92
3-73
3.63
3-63
3*45
3.82
3-73
3.73
3.63
3.63
3-92
4.02
3.82
3.73
3.73
3.82
3.82
3-82
3.85
3.84
3-84
3.62
3-86
3.91
3.91
3.68
3.58
3.62
4.07
3.63
3.70
3.69
4.23
3-64
3«50
3.62
3.77
3.42
3.57
3.53
3.21
3.56
3.55
3.53
3.62
3«62
3-62
3.70
3.47
3.20
3-43
3-36
3-47
3.30
-------
APPENDIX C: TABLE V.
RUN 6: GAS COMPOSITIONS
PAGE 6 OF 7
u>
DAY. HOUR
16.0030
16*0130
16*0230
16*0330
16*0430
16*0530
16*0630
16*0730
16*0830
16*0930
16*1030
16* 1130
16*1230
16* 1330
16*1430
16* 1530
16*1630
16*1730
16*1830
16.1930
16.2030
16.2130
16*2230
16*2330
17.0030
1 7 . 0 1 30
17*0230
17.0330
F L
02
Z
2*2
2*5
2*1
3*0
2.8
2.9
2.4
2-5
2*4
2.5
2-4
2.8
2-8
3*0
2.9
2.4
2.5
2*5
2*0
2*5
2*5
2.8
2*9
2*9
2.9
2.5
2.7
2-5
U E GAS
C02 VOL X
ANAL
13.2
13*2
13*5
12*7
13*2
13*2
13*2
13*2
13*2
13*2
13*2
13*2
13*2
13*2
13*0
13*5
13*5
13*5
13*5
13*2
13*5
13*2
13*2
13*2
13*0
13*2
13*2
13*5
CALC
14.1
13*9
14*2
13*5
13*6
13. 6
13*9
13*9
13*9
13*9
13*9
13*6
13*6
13*5
13*5
13*9
13*8
13-8
14*2
13*8
13*8
13*6
13.5
13*5
13*5
13*9
13*8
13*9
S02
PPM
294*
296*
297*
300*
299.
314.
324.
324*
324*
336*
354*
374*
379*
377.
394*
380*
364.
385.
395*
415*
415.
400*
374*
377.
400*
430*
439*
430*
REGENERATOR GAS
02 C02
% *
0* 10 1 .6
0* 10 1 *5
0* 1.7
0. 2*2
0*10
0* 10
0*
0*
0-10
0. 10
0.10
0.
0. 10
0*20
0* 10
0*10
0.20 S
0*10
0*10 j
0. 10
0*10
0*10
0.20
0.30
0*20 f
0*30
0*30
0.30
.7
.7
.6
• 5
.6
.8
• 6
.9
• 3
.0
• 6
.2
>.2
.3
?.0
.4
.0
*3
• 3
.0
1.7
.7
• 0
*4
SQ2
X.
7.0
7.4
7.0
6*6
6.8
7.0
7.0
7.0
7.0
7.0
6.6
6.6
6.4
6.2
6.8
6.0
6.2
6.2
6*8
8.2
5.8
6*2
7.0
6.2
5.8
5.8
5.2
5.4
GASI
FIER
02 VOL %
ANAL
15.4
15.4
15.4
15.7
15*7
15.7
15.5
15.5
15-5
15-5
15.4
15.0
15*0
15*0
15*0
15*0
1 5*0
1 5*0
15*4
1 5*4
16*0
16*8
17*2
17.6
18.0
18*5
18*8
19*1
CALC
16*4
16*2
16*4
16*6
16*3
16*0
16*1
16*2
16*1
16*2
16*0
15*9
15*9
16*0
16*1
15*7
15*5
15*5
15*4
15*6
15*4
15*5
15*6
1 5.6
1 5.6
18.5
18*8
19.1
INLET
GAS
C02 VOL %
ANAL
3*82
3*82
3*73
3.54
3*82
3*92
4*02
3*82
3*82
3*82
3*92
4*32
4*42
4.85
4.02
4.42
4.52
4.52
4.63
4.63
4.52
4.52
4.52
4.42
4.42
4.42
4.63
4.63
CALC
3*23
3*40
3*26
3* 12
3*40
3-68
3.46
3*46
3*46
3*46
3*54
3*70
3-70
3.70
3.48
3*84
3.99
3.99
3.99
3.84
4.06
3.99
3.9 1
3.9 1
3-83
1 .79
1 .59
1 .39
-------
U)
to
19.0330
19*0430
19.0530
19.0630
19.0730
19.0830
19.0930
19.1030
19.1130
19.1230
19.1330
19.1430
1530
1630
19.1730
19. 1830
19.1930
19.2030
19.2130
19.2230
19.2330
20.0030
20.0130
20.0230
19.
19
2.4
2.8
2.7
2.9
3. 1
3> 1
2.9
2.9
13.5
3.2
3.2
3-2
3.2
2.7
3.2
3.2
SHUT DOWN AT
4.0
4.2
3.4
3.3
3.0
2.9
3.1
2.9
2.8
2.2
2-2
2.5
2.5
2.5
2.5
2.5
2.5
2.4
2.7
3.0
3.2
3.0
3.2
3.2
12.4
12.2
13.0
13.0
13.0
13.0
13.0
13.1
13.2
13.8
13.8
13*1
13.2
13.2
13.2
13.2
13.2
13.2
13.0
13.0
12.7
12.7
12.7
12.7
14.0
13.7
13.8
13-7
13.5
13.5
14.0
13.5
17. 1 1
12.7
12.6
13.2
13.2
13.5
13.6
13.4
13.5
13.6
14. 1
14.1
13.9
13.9
13.9
13.8
13-8
13.9
13-9
13.7
13.5
13-3
13.5
13.3
13-3
41 4.
394.
394.
333.
323.
323.
336.
334.
30 FOR
112.
162.
218.
268.
304*
344.
369.
379.
369.
365.
365.
361.
326.
506.
293-
260.
276.
322.
268.
304.
349.
31 1.
307.
326.
0.40
0.40
0.30
0.20
0.20
0.30
0.30
0.30
.6
. 1
.7
.9
.7
.3
.7
.4
6.2
5.6
5.6
6.0
6.2
6.6
6.4
6.2
19.5
19.8
20.0
20.0
20.0
20.3
14.3
14.2
19.5
19.8
20.0
20.0
20.0
20.3
15.7
15.8
4.
4.
4.
4.
4.
4.
4.
4.
63
4?
42
21
32
42
63
21
1 .09
0.87
0.72
0.73
0.74
0.50
3*88
3.77
40 HOURS
0.50
0.50
0.30
0.50
0.30
0.30
0.40
0.20
0-20
0.30
0.30
0.30
0.20
0.20
0.20
0.50
0.30
0.
0.10
0.10
0. 10
0.20
0.10
0.
2.3
• 1
• 3
.3
• 4
.4
.8
.4
2*0
2.6
2.3
2-5
1.1
1.6
1.6
2.5
2-3
10.0
4.3
3-3
3-3
2.6
1.9
3.7
4.2
6.2
7.4
7.2
7.0
7.0
6.6
7.0
7.4
7.0
7.8
8.2
8.6
7.0
6.6
7.6
7.4
2.2
8.2
7.6
7.8
7.4
8.6
8.0
15.8
15.9
15.2
15.2
15.2
15.2
15.2
15.3
15.2
15-2
15.5
15.5
16.0
15.8
14.9
14.9
15.0
1 5.0
15.1
15. 1
15.3
15.2
15.2
1 5.0
16.0
16. 1
15.7
16.0
15.5
15.9
15.6
15.8
15.7
15.8
16.0
16.2
16.2
16.2
15.7
15.6
16.1
15.7
15.9
15.8
16.0
15.9
15.9
15.9
4.
3.
4.
4.
3.
3-
3.
3.
3.
3-
2.
3-
2.
2-
3.
3.
3.
3.
3.
3*
3.
2.
2.
3.
02
82
21
02
82
82
63
45
45
45
93
10
76
93
27
27
10
10
10
10
01
93
93
10
3.69
3.59
3.94
3.67
3-97
3.69
3.95
3.80
3-84
3.80
3*64
3.37
3.41
3*41
3.77
3.88
3*47
3.74
3-64
3* 76
3.58
3.61
3.61
3.61
-------
APPENDIX C: TABLE V-
RUN 6: GAS COMPOSITIONS
PAGE 7 OF 7
1
CO
to
00
1
DAY. HOUR
20.0330
20.0430
20*0530
20.0630
20.0730
20.0830
20.0930
20. 1030
20*1130
20.1230
20.1330
20.1430
20. 1530
20. 1630
20.1730
20* 1830
20. 1930
20.2030
20.2130
20.2230
20.2330
21 .0030
21 .0130
21.0230
21 .0330
21 .0430
F L
02
1 .2
0.4
1 .0
3.6
3.2
3*0
3.0
3.0
3.0
3.0
3*0
3.0
3.0
3.1
3.0
3.1
3*0
3.1
3.0
3*0
3.2
3.4
3-4
3.5
3.5
3*6
U E GAS
C02 VOL X
ANAL CALC
12.4 14.8
12-7 15.4
1 1-7
12.4
12.7
12.7
12.7
12.7
12.7
12-7
12.7
12.7
12.7
12.7
12.7
12.7
13-0
12.7
12.7
13.0
12.7
12.4
12.7
12.4
12.4
12-4
15.0
13.0
13.3
13.5
13.5
13.5
13.5
13.5
13.5
13.5
13.5
13.4
13.5
13.4
13.5
13.4
13.5
13.5
13.3
13.2
13.2
13.1
13.1
13.0
S02
PPM
330.
360.
355.
354.
354.
334.
326.
334.
342.
457.
-
-
-
326.
303-
278.
276.
278.
273.
273*
283-
281 .
283.
288.
293.
283.
REGENERATOR GAS
02 C02 S02
0.15 2.1 7.0
0.15 2.5 8-2
0.10
0.15
0*10
0.20
0.20
0.20
0.20
0.20
0.30
0.20
0.30
0.30
0.30
0.40
0.50
0.70
1.40
1 • 10
1.00
0.40
0. 10
0.20
0.10
0. 10
2.3
1.6
2.0
3.5
1 .9
2.8
4.2
2.9
4.7
3.2
2.3
2.5
2.8
1 .9
2.5
4.5
2.3
2.0
2.?
2.7
2.6
1 .9
2.3
2.3
8.2
7.8
7.4
7.0
6*2
6.8
7.4
7.2
7.6
7.4
7.0
6.2
7.2
6.8
7.0
6.8
6.8
7.6
7.0
8.0
7.4
7.0
6.2
8.2
GASIFIER
02 VOL X
ANAL CALC
15.1 15.3
15.1 15-0
15. 1
15.2
15.2
15.2
15.2
15-2
15.3
15.2
15.2
15.2
15.2
15.0
14.8
15.6
15.5
15.5
15.5
15.8
15.9
16.3
1 5.9
15.7
15.5
15.6
15.3
16.0
16.0
16.1
16.0
15.9
16.1
16.2
16.2
16.2
16. 1
16* 1
15-9
16.7
16.6
16.7
16.7
16. R
16.7
16.8
16.8
16.4
16.2
16.3
INLET GAS
CO 2 VOL X
ANAL CALC
3.01 3.61
3*10 3*68
3.01
3.01
3-01
2.93
2.93
2.93
2.93
2.93
2.93
2.93
2.93
3. 10
3« 10
2.76
2.76
2.76
2.76
2.68
?.68
2.28
2.68
2.76
2.84
2.84
3.35
3.55
3-55
3.46
3.53
3.61
3*46
3.38
3.38
3.38
3-45
3*46
3.61
3.06
3. 19
3.06
3.06
3-01
3.06
3.00
3.06
3.26
3.40
3-34
21.0530
3.2 12.7
STONE CHANGE
13.3 289. 0.20
3-3 8-0
15-5 16.2 3.01 3-41
-------
u>
10
vo
21.0630
21.0730
21.0830
21.0930
21.1030
21•1130
21.1230
1330
1430
• 1530
1630
• 1730
.1830
• 1930
.2030
.2130
.2230
21.2330
22.0030
.0130
.0230
.0330
.0430
.0530
.0630
.0730
.0830
21
21
21
21
21
21
21
21
21
21
22.!
22.
22.
22.
22.
22-
22.
22.
22.
22
.0930
.1030
22.1130
22*1230
1330
1430
1530
1630
1730
22
22
22
22
22.
3.5
2.6
2.6
2.7
2.8
2-6
2.8
2.8
2.8
3.0
3.2
2.9
3.0
3.0
2.8
2.8
3*4
3.2
3.0
3.0
3.2
3.2
3*0
3.0
3.0
3.0
3-4
3.0
3.0
3.0
2.6
2.5
2.6
2.2
2.9
3.0
12.4
13*0
13.2
13.2
13*0
13.0
13-0
13.0
13-0
13.0
12.7
13.0
13.0
12.7
13.2.
13.2
12.7
12-7
12.7
12.7
12.7
12.7
12.7
12.7
12.7
12.7
12-7
12.7
12.7
12.7
12.7
13.0
12.7
13-2
13.0
12.7
13. 1
13.8
13.8
13.7
13-6
13-8
13-6
13.6
13-6
13.5
13.3
13.5
13-5
13-5
13.6
13.6
13.2
13.3
13.5
13-5
13.3
13.3
13.5
13.5
13.5
13-5
13-2
13.5
13-5
13.5
13-8
13.9
13.8
14.1
13.6
13.5
324.
375.
402.
405.
374.
367.
357.
344.
354.
370.
369.
367.
383.
391 •
384.
346*
354.
369.
387-
443-
430.
410*
394.
334.
384.
334.
384.
409.
403-
393.
415.
474.
484.
518.
508.
497.
0.20
0.20
0.20
0.20
0.30
0.20
0.20
0-20
0.80
0.10
0.20
0.20
0-30
0.50
0.40
0.50
0.80
0.80
1 -00
0.70
0.70
0.80
0.80
0.80
0.80
0.80
1 .00
0.90
1 .00
0.90
1 • 10
1 .00
1 .00
0.90
0.90
0.20
2.3
3. 1
3.5
3. 1
2.5
3.3
2.3
2.8
2.9
3.3
3.5
4* 1
3.1
2. 1
3.3
3.9
2-6
3.0
3-0
3.5
3.9
3.7
3. 1
2.8
2.8
3.0
2.8
3.0
2.6
2.8
3.0
3. 1
4.3
2-6
3.5
2.P
7.4
6.2
6.2
6.4
6.4
6.2
6.4
5.4
5.8
5.6
5.6
5.4
5.6
4.8
6.2
5.8
5.8
6.2
5.4
5.6
5.6
5-4
5.4
4.8
5-0
4.2
5.4
5.6
4.2
5-6
5.4
5.4
5.0
5-0
5.0
4.2
15.5
15.4
14.9
15.3
15.3
15.5
15.6
1 5.8
1 5.6
15-2
15.3
15.2
15.2
IS. 1
15.1
15.1
15.0
15.1
14.6
14.2
14.5
14.5
14.5
14.8
15-0
15.0
14.9
14.9
14.9
14.9
14-9
14. 8
15.0
14.8
15. 1
15-?
16.0
16. 1
1 5.8
16.0
16.3
16.5
16.6
16.6
16.6
16*3
15.9
15.9
15.9
15.9
15.9
15.9
16.2
16. 1
15.7
15.7
15.9
15.9
15.7
15.7
15.7
15.7
16.3
15.9
15.9
16.0
15.9
15.9
16. 1
16.6
16.4
16-4
2.R4
3.01
3. 10
3.01
2.93
2.93
2.84
2.84
2.76
3. 10
3*01
3. 10
3. 10
3. 10
3. 10
3. 10
3*01
3*01
3.27
3.36
3-36
3*27
3.27
3. 10
3. 10
3. 10
3. 10
3. 18
3. 10
3. 10
3. 10
3. 18
3.01
3* 18
3-01
2.93
3.54
3.48
3.76
3.62
3.34
3. 19
3. 13
3.13
3. 13
3*40
3*61
3-69
3.69
3.61
3.69
3-69
3-47
3-47
3.75
3.75
3.61
3.61
3.75
3.75
3.75
3-75
3-41
3.57
3.57
3.52
3.52
3.59
3.37
3. 12
3.30
3.23
-------
RUN 6:
APPENDIX C: TABLE VI.
SULPHUR AND STONE CUMULATIVE BALANCE.
PAGE 1 OF 7
3AY.HOUR
1 -2230
1 -2330
2.0030
2.0130
2-0230
2.0330
2.0430
2.0530
2.0630
2.0730
2.0830
2.0930
2. 1030
2.1 130
2.1230
2.1330
2. 1430
2.1530
2.1630
2.1730
2.1830
2.1930
2.2030
2.2130
2.2230
2.2330
3.0030
3.0130
T
IN
0.124
0.26]
0.401
0*540
0.684
0.827
0.973
• 118
• 265
• 412
• 558
.707
• 856
2.005
2.152
2.301
2.451
2.600
2.748
2.897
3.046
3.195
3.344
3.491
3-641
3.789
3.938
4.086
0 T A L
K I L
FLUE
0.009
0.028
0.050
0.074
0.101
0. 128
0. 152
0.179
0.209
0.240
0.274
0.309
0.344
0.381
0.41 7
0.454
0.492
0.530
0.566
0.602
0.637
0.675)
0.702
0.734
0.766
0.795
0.825
0.854
S U L
0 M 0
REGEN
_
C-0.001)
0.064
0*164
0.271
0*412
0.555
0.683
0.820
0.949
1*074
• 184
• 309
.408
.505
• 604
• 693
.795
• 893
.991
2. 104
2.206
2.316
2.426
2.507
2.622
2.729
2*836
P H U
L S
FINES
0.001
0.003
0.004
0.006
0.007
0.009
0.010
0.013
0.023
0.038
0*042
0.046
0.060
0.090
0.095
0.126
0.158
0.162
0.167
0.171
0. 176
0. 180
0.209
0.216
0.222
0.228
0-233
PI. 238
R
IN-OU
0.115
0.231
0*282
0-297
0*304
0.278
0*256
0*243
0*213
0. 185
0.168
0. 168
0-143
0* 126
0* 135
0*117
0* 109
0* 1 13
0. 123
0* 132
0-129
0.139
0.117
0.116
0.146
0. 1 44
0- 1 51
0.1 58
EQUIVALENT BURNT STONE
KILOGRAMS
FEED REMOVED IN-OUT
7.0
10.5
10.5
10.5
10.5
15-1
24.8
32.9
40.7
48.8
57.4
63.6
69.2
75.4
82.4
91.9
98.6
105.3
1 14.2
123.9
134.4
146-0
155-2
164-9
175-7
185-4
196- 1
1*5
3.0
4.6
6. 1
7.6
9. 1
10.6
13.3
21.8
32.3
35*2
38.2
47.0
66. 1
69. 1
87.9
106.7
109.8
1 12.4
1 14.8
1 17.2
1 19-7
137.6
141 .4
145* 1
148*?
151.3
5.5
7.5
5.9
4*4
2.9
6.0
14.2
19.6
18.9
16*5
22.2
25*4
22*2
9*4
13*3
4.0
-8. 1
-4.4
1-9
9. 1
17.P
26.4
17.6
23-5
30*6
37. 1
44*R
52.0
-------
00
u>
3.0230
3.0330
3.0430
3-0530
3.0630
3.0730
3.0830
3.0930
3*1030
3.1 130
3.1230
3.1330
3.1430
3-1530
3*1630
3.1730
3*1830
3.1930
3.2030
3*2130
3-2230
3-2330
4.0030
4*0130
4.0230
4-0330
4.0430
4.0530
4*0630
4.0730
4.0830
4.0930
4.1030
4.1 130
4. 1230
4. 1330
4. 234 C
4.382 P
4.530 P
4. 680 0.
4.828 C
4.975
5. 123
5.271
5.420
5-569
5-720
5.871
6.023
6.173
6.324
6-476
6.628
6.780
6.932
7.083
7.236
7.386
7.539
7.690
7.841
7.992
8. 144
8.293
8.438
8.586
8.736
8.887
9.037
9. 187
9.338
9.490
J.883
1.9 1 1
1.940
J.968
J.996
.023
.051
.080
.109
. 139
• 171
• 203
.233
.261
-288
.315
.342
.369
.394
.418
.442
.466
.489
.51 1
• 536
.570
• 608
.643
.674
.707
.744
.784
.826
.875
1 .922
1 .973
2.944
3.040
3.148
3.261
3-382
3.485
3.589
3.696
3.803
3.915
4.034
4. 140
4.257
4-373
4-500
4.625
4.756
4.870
5.000
5.132
5.265
5.389
5.519
5.641
5.759
5.870
5.989
6.120
6.221
6.336
6.460
6.581
6.687
6.802
6-900
7.000
0.243
0.267
0.271
0.276
0.280
0*310
0.321
0*335
0*338
0.340
0*342
0.345
0-347
0*372
0.395
0.399
0.404
0.408
0.432
0.437
0.442
0.447
0.450
0.454
0.458
0.462
0.465
0.468
0.471
0.474
0.477
0.480
0.483
0.485
0.486
0.487
PI. 164
PI. 164
0. 172
0.175
0.170
0.157
0.162
0. 160
0.170
0. 175
0.173
0.183
0.186
0. 167
0. 141
0.137
0.126
0.133
0.107
0.096
0-.0ff6
0.084
0.081
0.083
0.087
0.091
0.082
0.062
0.071
0.069
0.055
0.042
0*040
0.026
0.030
0.030
216.4
226.6
237.9
248.7
258-1
264.9
274.8
282.9
293-1
303.4
310.7
319.3
327.6
335-4
344. 1
355-7
370.5
383.9
396*6
408*2
420.9
431*4
444.6
456.2
460*2
460.2
460.2
460.2
460.2
460.2
460.2
460.2
460.2
460.2
460-2
460-2
157.5
171.9
174.8
177. R
180.7
199.5
206.6
216.0
217.7
219.3
220.9
222.6
224.2
240*8
255*6
258.7
261*8
264*9
261-4
285.0
288.6
292-2
295-0
297.9
300.8
303.6
306.5
308.9
31L1
313.3
31 5.6
317.9
320.2
321.?
322.1
323- 1
5* .9
54.7
63- 1
70.9
77.4
65.3
68.2
66.9
75.5
84. 1
89.7
96.7
103-4
94.6
88.5
97.0
08.7
19-1
15-2
23.2
32.3
39.2
49.5
58.2
59.4
56.5
53.7
51.3
49. 1
46.9
44*6
42. 3
40. 0
39.0
138. 1
137. 1
-------
APPENDIX C: TABLE VI.
RUN 6: SULPHUR AND STONE CUMULATIVE BALANCE-
PAGE 2 OF 7
u>
Ui
to
AY. HOUR
4.1430
4.1530
4.1630
4.1730
4.1830
4*1930
4.2030
4 • 2 1 30
4.2230
4*2330
5.0030
5.0130
5.0230
5.0330
5.0430
5*0530
5.0630
5.0730
5.0830
5*0930
5* 1030
5.1130
5.1230
5.1330
5.1430
5-1530
5*1630
5* 173d
T 0
K
IN
9*640
9.791
9.942
1 0 .09 3
10.243
10*395
10*545
10*696
10*843
10.994
1 .151
1 .301
1 .450
1 .600
1 .751
1 .901
12*051
12*201
12*351
12*499
12*653
12*805
12*955
13*104
13.253
13*404
13*553
13*703
T A L
I L
FLUE
2.020
2.067
2.108
2.144
2.181
2.213
2.239
2.263
2.281
2.298
2.317
2.335
2.356
2.378
2.402
2.432
2.452
2.472
2.493
2.513
2.533
2.552
2.572
2.589
2.606
2.624
2-642
2.66{*
S U L
0 M 0
REGEN
7.109
7.223
7.327
7.437
7.550
7.669
7.778
7*889
7*992
8*087
8*200
8*305
8*376
8*485
8*606
8*698
8*785
8.881
8.986
9.086
9.197
9.302
9.381
9.493
9.618
9*729
9*834
9.940
P H U
L S
FINES
0*490
0*513
0.516
0.535
0.537
0.539
0.541
0*543
0*564
0*566
0*568
0*570
0*573
0*576
0*582
0*587
0*592
0*598
0*601
0*605
0*617
0*620
0*626
0-.631
0*636
0.640
0.662
0.697
R
IN-OU
0*022
-0.01 1
-0.009
-0.025
-0*025
-0*025
-0*013
0*002
0*006
0*043
0*066
0*091
0. 146
0.161
0* 161
0* 184
0*222
0*249
0*270
0.295
0.307
0*330
0*375
0*390
0*393
0*41 1
0.414
0.406
EQUIVALENT BURNT STONE
KILOGRAMS
FEED REMOVED IN-OUT
460.2
467*2
475*8
484*2
492-5
499.3
507.3
517.9
525*9
535.4
546.4
555.6
562
571
579
588
596
604*6
615.7
624*3
632*9
642*6
653*4
664*2
675*5
685.7
696- 8
706.5
3
2
8
2
3
324.9
342*7
345*4
360*5
362*1
363*5
364*9
366*3
382*8
384*4
386.4
388.4
390.4
394*0
399*4
404.8
410.2
415.6
419*5
423*0
433*9
437*3
442*4
445*7
449* 1
452-4
469.7
496.0
135.3
124*5
130*5
123*7
130*4
135.8
142.4
151*5
143-1
151
160
167
171
1
3
177*2
180*4
183*4
186*1
189*0
196-
20 I
199.0
205*3
210*9
218*4
226.4
?33*3
227.1
210.4
-------
U)
u>
5.1830
5.1930
5-2030
5.2130
5.2230
5.2330
6*0030
6.0130
6.0230
6.0330
6.0430
6*0530
6.0630
6*0730
6.0830
6.0930
6* 1030
6.1 130
6.1230
6*1330
6. 1430
6.1530
6.1630
6.1730
6. 1830
6 . 1 9 30
6.2030
6.2130
6.2230
6*2330
7.0030
7.0130
7.0230
7.0330
7.0430
7.0530
13.852
-
14.002
14. 151
14.299
14.449
14.598
14*747
14.895
15-042
15. 194
15.344
15.492
15.642
15.791
15.941
16.093
16.241
16.390
16.539
16.688
16.839
16.991
17.142
1 7 . 29 7
17.450
17.600
17.752
17.903
18.056
IB. 209
18.360
18.512
18*664
18*81 5
2.679
-
2.719
2.755
2.792
2.829
2.861
2.894
2.933
2.970
3.010
3*044
3.078
3-114
3-149
3-182
3-215
3.247
3-278
3-309
3-341
3.371
3.403
3.436
3.468
3-502
3.534
3-566
3.599
3.630
3.660
3.688
3.719
3.752
3.784
10.056
-
10. 160
1 0 . 29 2
10.400
1 0 . 50 7
10.622
10*731
10.836
10.944
1 1 .047
1 .154
1 .260
1 .368
1 -474
1 .580
1 .690
1 .797
1 .899
12.000
12.093
12.187
12.266
12.368
12.468
12.569
MISSED
12.665
12.758
12.821
12.900
12.985
13.089
13.202
13.313
13-409
0.700
-
0.703
0.707
0.711
0.715
0.734
0.739
0.757
0.763
0.769
0.776
0.782
0-788
0.795
0.803
0.823
0.843
0*860
0.880
0.909
0.918
0.926
0.931
0.944
0.951
0.41 7
-
0.420
0.397
0.396
0.397
0.381
0.383
0.370
0.365
0.367
0.370
0.372
0.372
0.374
0.377
0.366
0.354
0.354
0.349
0.345
0.363
0.396
0.408
0.416
0.428
714.0
721 .5
731 .2
740. 1
747.9
755.8
764.7
771 .7
780.0
789.2
804.3
815.3
827.4
841 .4
852.8
868*7
876*2
889.7
902.3
912.0
925*2
941*1
952*7
968*6
977.5
992* 1
498.4
509.8
512.0
515.1
518.4
521 .8
536- 1
540.5
554.0
559.0
564*0
569*0
573*9
578.8
584.2
590*2
605*3
620*6
633*4
648*6
670.3
676*8
682*0
686* 1
695*9
701. 1
215.6
211.7
219.2
225.0
229.4
233.9
228.5
23L2
226.0
230. 1
240.2
246.3
253-5
262.6
268.5
278.5
270.8
269.0
269.0
263.4
255.0
264.4
270.7
282.6
281 .6
290.9
DATA READING
0.958
0.983
1 .008
1 .026
1 -035
1 .049
1.066
1 .080
1 .096
0.444
0.444
0.475
0.499
0.530
0.534
0.525
0.517
0.525
1003.9
1015.8
1023.3
1 0 38 • 1
1053.8
1064.5
1078-3
1089.6
1 104.4
706-3
724-2
741 .3
754-2
760.2
769.9
780.8
790.5
800.9
297.6
291.5
282.0
284.0
293.5
294.6
297.5
299. 1
303.5
-------
APPENDIX C: TABLE VI.
RUN 6: SULPHUR AND STONE CUMULATIVE BALANCE-
PAGE 3 OF 7
TOTAL
DAY. HOUR K I L
IN FLUE
7.0630 18*965 3-813
7.0730 19.116 3*842
7.0830 19.267 3-869
7.
7.
7.
7.
7.
7.
1 M
1 7.
w 7.
U> _
» 7.
I 7*
7.
7.
7*
7.
7.
8*
8*
8*
8*
8*
8*
8*
8.
8*
8*
0930
1030
1130
1230
1330
1430
1530
1630
1730
1830
1930
2030
2130
2230
2330
0030
0130
0230
0330
0430
0530
0630
0730
0830
0930
19,
19.
19.
19.
20.
20.
20.
20.
20.
20.
20*
21*
21.
21.
21.
21.
21.
21.
22.
22*
22.
22.
22.
22.
23.
.417
.567
• 718
.868
.019
• 170
321
471
621
773
920
069
219
367
526
685
841
992
143
293
444
595
746
896
047
3.895
3.920
3.945
3.972
4.001
4.033
4.062
4-094
4.126
4*158
4.186
4.217
4*251
4.288
4*329
4*369
4*41 1
4*447
4*482
4*521
4.560
4.601
4.643
4*686
4*731
S U L
0 M 0
REGEN
13*509
13*615
13*721
13.
.834
13-950
14.
060
14.181
14.
14.
289
416
14*531
14*
14*
14*
14*
15*
15*
15*
15*
15.
15*
15*
15*
15*
16*
16.
16*
16.
16*
648
760
869
982
091
197
306
419
534
648
756
861
976
092
205
318
432
546
P H U
L S
FINES
• 116
• 124
• 131
• 151
• 158
• 164
• 208
• 213
• 219
• 226
• 231
• 235
• 239
• 241
• 246
• 251
.266
• 271
• 277
• 282
• 286
-290
• 296
• 302
• 316
• 325
• 331
.335
R
IN-OUT
0.526
0*535
0.547
0*536
0*539
0*549
0*507
0.515
0*502
0*501
0*499
0*500
0*507
0-510
0*515
0.519
0*508
0.507
0.505
0.501
0*503
0*508
0.500
0*490
0.474
0.459
0*447
0*434
EQUIVALENT BURNT STONE
K ILOGRAMS
FEED REMOVED IN-OUT
1115*2 814.6 300.6
1128*7 820.3 308.4
1141*1 825.7 31S.4
I 1 50 . 5
M 59 . 4
1166.1
1 1 69 . 6
1 173.7
1 1 78 * 0
1 183*9
1190*4
1196.8
1200.3
1204. 1
1207.3
1211. 1
1214.3
1218.4
1221 .6
1225.7
1230.0
1234.0
1237.8
1241 .0
1244.5
1248.8
1253.4
125B.0
837.8
842.6
846*9
87] .4
874.5
878.6
883*5
887.2
889.8
892.0
894.0
896.7
900.0
908.9
912.1
915.3
918.2
921 .0
923.5
926.6
930.2
937.6
942.9
946.7
949. 1
312.7
316.8
319.2
298.2
299. 1
299.4
300*4
303* 1
307. 1
308*3
310. 1
310.7
311*1
305*4
306*2
306.4
307.4
309.0
310.5
311.2
310.8
306-9
305.9
306.7
30R.9
-------
8.
8*
8*
8.
8.
8*
8.
8*
8.
8*
8*
8.
8*
8*
9.
9.
9.
I 9.
u> 9-
VA/
w 9.
9.
1 9.
9.
9.
9.
9.
9.
9.
9.
9.
9.
9.
9«
9 •
9-
9-
1030
1130
1230
1330
1430
1530
1630
1730
1830
1930
2030
2130
2230
2330
0030
0130
0230
0330
0430
0530
0630
0730
0830
0930
1030
1 130
1230
1330
1430
1530
1630
1730
1830
1930
2030
2130
23.198
23.349
23*500
23*650
23*800
23-951
24*102
24*245
24*380
24*513
24*646
24*777
24*912
25*045
25*178
25*312
25.445
25.579
25*713
25.847
25-981
26.116
26.250
26*385
26*513
26*642
26.771
26.902
27.035
27.167
27.298
27.436
27.574
27.698
27.827
27.957
4-776
4*820
4.863
4.906
4*949
4.992
5.038
5.083
5.122
5.157
5.192
5.228
5.264
5.299
5.334
5.373
5.412
5.450
5.489
5.535
5*580
5.626
5.672
5.712
5.749
5.786
5.821
5.854
5.886
5.916
5*952
5.990
6.023
6.051
6.078
6. 118
16
16
16
17
17
17
17
17
17
17
17
17
17
18
18
18
18
18
18
18
18
18
18
19
19
19
19
19
19
19
19
19
19
20
20
20
.665 1
• 786 1
-907 1
• 028 1
.142 1
• 255 1
.368 1
.467 1
.567 1
• 671 1
.776
.882
.982
.087
.188
.287
• 389
.487
.589
.689
.785
.878
.978
• 056
. 147
.234
• 329
.431
• 531
.632
.740
.843
.931
.018
• 107
.199
• 339
• 343
.347
• 374
.377
.381
• 384
• 386
.389
1.391
• 394
• 398
.402
• 436
.440
• 443
.447
.451
.454
• 458
• 462
• 466
.469
.472
.475
.478
• 482
.485
• 488
.490
• 494
.500
.503
.506
• 533
.534
0.418
0.400
0.383
0.343
0.331
0.322
0.313
0.308
0.303
0.295
0.284
0.270
0.264
0.223
0.216
0.208
0.197
0.191
0.180
0.165
0.154
0.145
0.131
0. 145
0.143
0. 144
0.139
0. 132
0.131
0.129
0.111
0.103
0.1 17
0.123
0. 109
0. 107
1261.5
1265.0
1268.5
1272.0
1274.7
1279-3
1 28 3 • 9
1288-7
1294.4
1300.6
1303.8
1306.8
1310-5
1316*2
1 320 • 2
1324.8
1 328 • 0
1331.3
1334.0
1337.5
1341.2
1345*6
1350.1
1354.7
1359.0
1364.4
1369.8
1376.0
1 38 1 • 7
1 388 - 4
1393.8
1 40 1 • 1
1408.9
1417.5
1424.2
1429.6
951.
953.
956.
970.
972.
974-
976.
977.
979.
980.
982.
984.
987.
1005*
1008.
1010.
1012.
1015.
1017.
1019.
1021.
1024*
1026*
1028.
1030.
1032.
1034.
1036.
1038.
1040.
1043-
1047.
1049.
1051.
1070.
1071.
4
7
1
0
4
5
2
6
0
4
3
8
4
6
0
3
7
0
3
6
9
2
3
2
3
5
6
8
7
4
3
4
3
3
2
0
310. 1
31 1.3
312.4
302.0
302.3
304.8
307.6
311.1
315.4
320.2
321.5
321.9
323.2
310.6
312.2
314.5
315-4
316.3
316.7
317.9
319.3
321*3
323.8
326.5
328.7
331.9
335.2
339.2
342.9
348.0
350.5
353.6
359.5
366.2
354.0
358.6
-------
APPENDIX C» TABLE VI.
RUN 6: SULPHUR AND STONE CUMULATIVE BALANCE-
PAGE 4 OF 7
DAY.HOUR
TOTAL
K I L
IN FL UE
SULPHUR
0 M 0 L S
REGEN FINES IN-OUT
EQUIVALENT BURNT STONE
KILOGRAMS
FEED REMOVED IN-OUT
9.2230 28-088
6.156 20*280 1.535 0.117
1437.7 1071.8
SHUT DOWN AT 9.2230 FOR 23 HOURS
365.9
10.2130
1
u>
u
o\
1
0.2230
0.2330
.0030
.0130
.0230
.0330
.0430
• 0530
.0630
.0730
• 0830
• 0930
.1030
• 1130
• 1230
0330
• 1430
• 1530
.1630
• 1730
• 1830
• 1930
• 2030
.2130
.2230
28.222
28.363
28*504
28*645
28*784
28*921
29.057
29.198
29.336
29.472
29.607
29-742
29.878
30.016
30.153
30*291
30 • 428
30-565
30.702
30.839
30.976
31*111
31.248
31 .384
31.518
31.654
6*194
6*230
6*263
6*297
6*328
6*357
6*383
6*409
6*435
6.458
6*479
6*500
6*520
6*541
6.564
6.588
6*610
6*631
6*650
6*670
6.689
6.710
6*733
6*757
6.782
6.808
20*338
20*433
20 * 542
20*645
20.727
20*827
20-929
21 .025
21 .125
21-221
21-315
21 »404
21.491
21*566
21-656
21.748
21 .820
21*884
21.942
22.014
22.091
22.167
22.269
22.375
22.474
22.554
• 536
.537
• 540
• 545
.550
• 556
• 563
.570
.594
• 602
.625
• 659
.689
.694
.717
.723
.742
.750
.759
.770
• 781
.788
.794
• 801
• 807
• 817
0.154
0.163
0*159
0-158
0-179
0*180
0.183
0*194
0.183
0.191
0.188
0.180
0.179
0.215
0.215
0.232
0*255
0*300
0.350
0*386
0.415
0.447
0.451
0.451
0.456
0.475
1451-4
1467.1
1479.5
1490.0
1503.7
1519.9
1535*8
1548-2
1555.7
1573.5
1591.0
1606*9
1625.2
1642-5
1659.7
1677.0
1693.9
1712.5
1730.0
1747.8
1766.7
1782.8
1795.5
1795.5
1804.9
1817.3
1072.6
1073*4
1075*6
1079.1
1082.7
1087*1
1091*8
1096.5
11 14.0
1 1 19.8
1136.0
1160.5
1181.9
1 185-5
1202.6
1206.7
1221.0
1226.5
1233.1
1240.8
1249.6
1254.4
1259.2
1263.9
1268.6
1276.5
378.9
393.7
403*9
410.8
421.0
432.8
443*9
451.6
441.7
453.7
455.0
446.4
443*4
456.9
457. 1
470.3
473.0
486. 1
496.9
507.0
517.0
528.4
536-3
531.6
536.3
540.9
-------
11.2330 31.788
12.0030 31.922
12*0130 32.057
12.0230 32.190
12.0330 32.324
12.0430 32.462
12.0530 32.599
12-0630 32.733
12.0730 32.868
12.0830 33.002
12.0930 33.137
12.1030 33.271
12*1130 33.406
12.1230 33.542
12.1330 33.677
12*1430 33*812
12.1530 33.948
I 12*1630 34*083
w 12-1730 34.217
i3 12*1830 34*352
12*1930 34*487
' 12.2030 34.621
12.2130 34.757
12.2230 34.890
12.2330 35*023
13*0030 35.156
13.0130 35.290
13-0230 35.426
13-0330 35-560
13-0430 35-692
13-0530 35.825
13.0630 35.960
13-0730 36-091
6.830 22.613 .839 0-507
6.851 22-674 .843 0.554
6-870 22.742 .869 0.575
6-890 22*819 .875 0.606
6.914 22.898 «890 0-622
6.941 22.969 .900 0*652
6*966 23*027 .910 0-697
6-987 23-084 .920 0.741
7.006 23*153 .928 0*781
7.024 23.221 -932 0.824
7.043 23-271 .937 0.886
7.062 23.353 -962 0.893
7-083 23*421 .990 0*912
7*105 23-484 2-019 0-934
7-127 23-553 2-039 0-958
7-147 23-619 2-059 0-988
7-166 23*687 2*073 .022
7.186 23*739 2*083 .075
7.207 23-804 2*096 -110
7*231 23*874 2* 09 .139
7-256 23-938 2- 18 -175
7.280 24*008 2* 37 *196
7*304 24*071 2- 47 -234
7-326 24-147 2- 63 *254
7.348 24-224 2- 72 -280
7.370 24.305 2. 83 .298
7.396 24-361 2-196 .338
7-422 24-443 2-209 -351
7.446 24.513 2.222 .378
7-469 24-588 2-234 .400
7.493 24.662 2.244 .427
7-517 24.730 2-257 -456
7-539 24-793 2-273 -487
1835-1 1292-6
1848-0 1296.2
1863-1 1315-2
1870.4 1320- 1
1884-1 1331.6
1902*2 1338-7
1919.7 1346-6
1934. 0 1354.4
1948-5 1360.2
1965.2 1363-8
1983.0 1367.4
1994.9 1386.1
2005*7 1406*6
2023.4 1428.5
2040.2 1443*3
2057.1 1457.7
2071.7 1468-0
2085.7 1475-4
2096*5 1484*8
2109*7 1494*3
2120.2 1501.5
2130*4 1515*3
2142.5 1522.5
2152-2 1534.2
2163.8 1540.8
2176.5 1549.1
2186.2 1559.1
2200*7 1569*2
2211.8 1579-4
2224.4 1588*3
2236.3 1595.8
2248-4 1605.5
2266-5 1617.5
542-5
551 .8
547.9
550-3
552-5
563-5
573-2
579-6
588-4
601 -4
615.6
608.8
599. 1
595.0
596.9
599.5
603.6
610.3
61 1 *6
615*4
618.6
615* 1
620. 1
618. 1
623.0
627.4
627. 1
631.5
632.4
636*2
640-5
642-9
649-0
-------
APPENDIX C: TABLE VI-
RUN 6: SULPHUR AND STONE CUMULATIVE BALANCE
PAGE 5 OF 7
TOTAL
DAY. HOUR K I L
1
t*>
CO
fr»
OU
1
13.
13.
13.
13*
13-
13*
13-
13-
13.
13.
13.
13.
13.
13-
13-
13*
14-
14.
14-
14-
14.
14.
14*
14*
14.
14-
14.
14-
0830
0930
1030
1130
1230
1330
1430
1530
1630
1730
1830
1930
2030
2130
2230
2330
0030
0130
0230
0330
0430
0530
0630
0730
0830
0930
1030
1130
IN
36.228
36.362
36.497
36.631
36.766
36.901
37.035
37.169
37.304
37.438
37.573
37.708
37.839
37.972
38. 109
38.245
38*382
38 * 520
38 • 6 59
38*796
38*934
39*074
39.213
39*351
39 * 489
39.621
39.761
39-901
FLUE
7 • 560
7.580
7.603
7.626
7.647
7.669
7.692
7.717
7.746
7.776
7.807
7.840
7.880
7.945
8.008
8.064
8*114
8* 165
8*218
8*271
8*323
8*373
8*430
8*487
8*540
8*589
8*637
8*683
SULPHUR
0 M 0 L S
REGEN
24*853
24.894
24.947
25.008
25.073
25.150
25*258
25-351
25-447
25-543
25-630
25.711
25.794
25.851
25-897
25.957
26.019
26.091
26-153
26.210
26.276
26.335
26.400
26.456
26-512
26.565
26-614
26-686
FINES IN-OUT
2-289
2.
305
2.320
2.
2-
2.
2-
2-
2-
2-
2-
2-
2-
2-
2-
2.
2.
2*
2.
2.
2.
2.
2.
2.
2.
2.
2-
2-
334
349
361
384
394
401
408
416
423
432
442
452
461
470
480
489
499
508
517
527
537
547
557
567
573
• 525
• 583
• 625
• 663
-697
-721
-702
• 707
• 710
.711
-720
-734
-733
.734
• 752
.763
.779
.784
.799
• 816
• 827
-848
• 856
• 871
• 890
-910
-944
.958
EOUI VALENT BURNT STONE
KILOGRAMS
FEED
2279.4
2294-8
2306. 1
2319.6
2333-3
2346.8
2356-5
2363-2
2373-2
2382-6
2393-9
2405-2
2415-7
2425-7
2437-8
2448*9
2458*3
2468-3
2477*4
2483.6
2492.8
2503-6
2513.5
2525-4
2538.1
2545.9
2555-0
2563-9
REMOVED
1629-3
1641-0
1652-0
1662-1
1672-8
1 68 1 - 8
1697.7
1705.1
1710.4
1716-8
1723-1
1729-0
1735.9
1743.6
1751.0
1757-9
1765.2
1772.7
1780.2
1787.7
1795-2
1802-7
1810.6
181R.9
1827.2
1835-5
1843- P
1 8 49 - 3
IN-OUT
650. 1
653.7
654. 1
657-4
660.5
665-0
658*8
658. 1
662.8
665.8
670.8
676.2
679.9
682. 1
686.9
690.9
693. 1
695.6
697.2
695.9
697.6
700.9
702-9
706-5
710.3
710.3
711.?
714.6
-------
1
1
1
1
1
I
1
1
1
1
t
1
1
1
1
1
1
• 1
UJ 1
OJ .
vo «
, 1
1
I
1
1
1
1
1
1
1
1
1
1
1
1
1
4. 1230
4. 1330
4* 1430
4. 1530
4. 1630
4. 1730
4 . 1 8 30
4. 1930
4.2030
4 . 2 1 30
4.2230
4.2330
5.0030
5.0130
5.0230
5.0330
5.0430
5.0530
5.0630
5.0730
5.0830
5.0930
5.1030
5. 1 130
5. 1230
5. 1330
5.1430
5. 1530
5. 1630
5. 1730
5. 1830
5. 1930
5.2030
5.2130
5-2230
5.2330
40.041
40. 180
40-320
40.461
40.601
40 • 7 4 1
40.882
41.023
41. 163
41.304
41.443
41.582
41.724
41.866
42.009
42.155
42.304
42.455
42.603
42.752
42-901
43-049
43- 193
43.333
43.473
43.612
43.749
43-886
44.025
44. 163
44.301
44.440
44.579
44.716
44-852
44-989
8
8
8
8
8
8
9
9
9
9
9
9
9
9
9
9
9
9
9
9
9
9
9
9
9
9
9
9
9
9
9
9
9
9
10
10
.729
.775
• 820
• 867
-915
.962
.01 1
.059
• 107
• 153
. 198
.243
.295
.350
• 402
.453
• 494
.533
.568
.598
• 628
.661
• 694
.722
.748
.773
.799
.824
.850
.875
.899
• 922
.948
.976
.002
.029
26.763
26.841
26.913
26.988
27.056
27. 132
27.201
27.271
27.341
27.392
27.472
27.551
27.612
27.684
27.756
27.827
27.921
28.021
23.123
28*221
28.325
28.411
28.504
28 • 59 4
28.684
28.769
28.859
28.937
29.021
29.108
29. 190
29.272
29.361
29.444
29.522
29.604
2.577
2.580
2.583
2.603
2.623
2.630
2.637
2.644
2.652
2.659
2.666
2.676
2.689
2.702
2.715
2.728
2.741
2.754
2 • 7 59
2.766
2.774
2-784
2.792
2-799
2.805
2.812
2.819
2.826
2.833
2.840
2.847
2.854
2.860
2.867
2.874
2.882
1 .972
1 .984
2.005
2.002
2.007
2.018
2.033
2.049
2.064
2. 101
2. 107
2. 1 13
2. 129
2. 130
2. 137
2. 148
2. 148
2. 148
2. 153
2. 167
2. 174
2. 194
2.203
2.219
2.236
2.258
2.272
2.299
2.321
2.340
2-364
2.392
2.409
2.429
2.453
2-474
2571 .
258 0-
2588-
2596-
2603-
2613-
2625.
2635.
2644.
2654.
2663.
2669.
2679.
2690.
2700.
2710.
2720*
2728.
2736.
2746-
2756-
2764.
2774.
2784.
2792.
2802.
2809.
2818.
2825.
2838.
2849.
2860.
2871 .
2881 •
2892.
2902.
7
4
7
3
3
2
6
3
2
2
1
8
2
6
5
8
5
6
4
3
0
7
4
3
7
1
9
0
3
2
8
3
4
3
4
3
1851.9
1854.5
1857.1
1875.7
1893-4
1899.6
1905.8
191 1 .9
1918- 1
1924.2
19 30 • 4
1 9 39 . 1
1950.4
1961 .7
1973.4
1985.6
1997.8
2009.9
2015.1
2020.8
2028.5
2037.3
2044.7
2050.4
2056.2
2062.0
2068-0
2074.2
2080-4
2086.6
2092.4
2097.8
2103.2
2108-6
21 14.7
2121 .4
719.8
725-8
731 .6
720.6
709.9
713.6
719.9
723.4
726. 1
729.9
732.7
730.7
728.8
728.9
727. 1
725.2
722.7
718.6
721.3
725.5
727.6
727.3
729.7
733-9
736.5
740. 1
741-9
743.8
744.9
751 .6
757.4
762.5
768.1
772.7
777-7
780-9
-------
APPENDIX C: TABLE VI.
RUN 6: SULPHUR AND STONE CUMULATIVE BALANCE-
PAGE 6 OF 7
T
UAY.HUUR
1
U>
*»
1
16.0030
16.0130
16*0230
16.0330
16.0430
16.0530
16.0630
16*0730
16*0830
16.0930
16. 1030
16. 1 130
16. 1230
16. 1330
16. 1430
16. 1530
16*1630
16. 1730
16.1830
16.1930
16.2030
16.2130
16-2230
16.2330
17.0030
1 7 . 0 1 30
17.0230
17.0330
IN
45.126
45.263
45.402
45-535
45.665
45.800
45.934
46.068
46.202
46.335
46*469
46.600
46-732
46.863
46.994
47.124
47.256
47.386
47.517
47.648
47.780
47.91 1
48.042
48.172
48*303
48-434
48.566
48 • 69 7
0 T A L
K I L
FLUE
10.056
10.084
10.112
10. 140
10. 167
10.197
10.227
10.257
10.286
10.317
10.350
10.384
10.419
10.454
10.490
10.524
10.557
1 0 . 59 1
10*626
10.663
10.701
10.737
10.771
10.806
10.843
10.882
10.922
10.960
S U L
0 M 0
REGEN
29 . 68 7
29.774
29.856
29.933
30.012
30-094
30.176
30.259
30.342
30.425
30*503
30 • 580
30.653
30.724
30.802
30.869
30.942
31.015
31 .100
31.207
31 -280
31 .359
31 .449
31 .530
31.607
3 1 • 68 7
31 .758
31 .833
P H U
L S
FINES
2.890
2*898
2*906
2.913
2*^921
2.930
2.939
2.948
2.957
2.967
2*976
2.985
3.027
3.037
3.077
3* 104
3. 1 16
3. 142
3. 167
3- 175
3. 183
3- 189
3. 196
3.203
3-21 1
3.218
3.228
3.241
R
IN-OUT
2.493
2.507
2.529
2.548
2.565
2-579
2.592
2.6ft5
2.616
2.626
2.641
2.651
2.633
2-649
2.625
2.628
2.641
2.638
2.624
2.603
2.617
2.626
2.626
2.633
2-642
2.647
2.658
2.663
EQUIVALENT BURNT STONE
K I
FEED
2912-8
2922.5
2933-3
2942.8
29 49 . 2
2956.5
2967.8
2976.2
2982.9
2989.4
2997.7
3006.6
3016-8
3030. 1
3041 -4
3052.7
3067.0
3073.4
3082-6
3096.3
3 1 09 . 3
3124.6
3136.7
3147.0
3157.2
31 66.4
3174- f?
3188.5
L 0 G R A
REMOVED
2128. 1
2134-6
2141 .0
2147.3
2154.2
2161 .5
2 1 68 . 8
2176.2
2183-8
2191 .3
2198.8
2206.1
2242.2
2249.5
2284.4
2307.4
2316.6
2338.4
2359.5
2365.5
2370.8
2375.4
2380.0
2385.3
2391 .5
2397.7
2405.7
2415.7
M S
IN-OUT
784.8
787.9
792.4
795.4
795.0
795.0
799 • 0
799.9
799. 1
798.0
799.0
800.5
774.6
780.6
757.0
745.3
750.4
735.0
723. 1
730.8
738*5
749.3
756.8
761 .7
765.7
7 68. 7
768.5
772. R
-------
u>
rfa.
17.0430
17.0530
17.0630
17.0730
17.0830
17.0930
17. 1030
17.1 130
19.0330
19*0430
19-0530
19.0630
19.0730
19*0830
19.0930
19. 1030
19. 1 130
19. 1230
19. 1330
19*1 430
19.1 530
19.1 630
19. 1730
19* 1830
19 * 1930
19 .2030
19 .2130
19.2230
19 .2330
20 .0030
20 «01 30
20.0230
48.830 10.998
48.962 11-034
49.095 1-070
49-227 1-101
49.360 1*131
49 . 49 0 1*161
49.620 1.191
49.751 1.222
SHUT DOWN AT 17
49.882
50.013
50.145
50-277
50 • 408
50.540
50.673
50.806
50 . 9 4 1
51 .076
51 .212
51 .349
51 .483
51 .614
5 1 • 7 49
51-882
52.015
52. 148
52.281
52.416
52-549
52.681
52*812
• 233
• 249
• 270
.295
.323
.356
.390
.426
.461
.494
.528
.562
.592
• 638
.665
.689
.714
.743
.768
.797
.831
.860
.889
52*946 11-920
31.919 3.253
31.996 3.266
32.073 3.280
32.156
32-240
32.328
32.391
32-475
.1130 FOR
32-527
32-603
32.695
32*785
32-874
32.961
33.045
33* 132
33-223
33*314
33*409
33.513
33-621
33.712
33.797
33.895
33.983
34-009
34. 107
34. 195
34.290
34.385
34.494
34.600
3.293
3.307
3.322
3-727
3-737
2.660
2.666
2.672
2.678
2.682
2.679
2.312
2.318
3201 .9
3214.3
3225-4
3234.3
3248.8
3259.9
3269.3
3280.1
2425.6
2436.2
2447.6
2458-3
2469. 1
2480.7
2742.5
2749.0
776- 4
778-1
777-3
776-0
779-7
779.?
526.8
531 • I
40 HOURS
3-747
3.754
3.758
3.762
3.767
3-772
3-777
3.781
3.784
3.788
3*792
3-796
3.801
3.805
3-81 1
3.816
3-821
3-826
3.830
3.836
3-842
3.847
3-852
3-858
2.376
2.407
2.422
2.434
2.444
2.452
2.461
2*467
2*472
2*480
2*483
2-478
2*469
2*459
2*477
2*483
2-497
2.570
2.576
2.587
2.586
2-589
2-577
2.568
3290.3
3303.5
3311.3
3320.8
3330-2
3338.6
3346.9
3356.6
3366.0
3375.5
3385.7
3395.9
3404.6
3413.7
3423-4
3431.5
3439. 1
3449.8
3460. 1
3468.4
3478-1
3485.9
3493.5
3500-2
2755.5
2760.1
2762.8
2765-6
2768-7
2771 .9
2775.0
2777.7
2779*8
2782.3
2785-3
2788*4
2791*7
2795.3
2799. 1
2802.9
2806.8
28 1 0 - 3
28 1 3 • 5
2817.3
2821 .8
2825.8
2829-4
2833-8
534.8
543.4
548.6
555. 1
561 .5
566.7
571 .9
578.9
586-3
593-2
600*4
607. 5
612.8
618.5
624.4
628.6
632.3
639« 5
646*6
651 • 1
656*3
660. 1
664- 1
666-4
-------
APPENDIX C: TABLE VI.
RUN 6: SULPHUR AND STONE CUMULATIVE BALANCE.
PAGE 7 OF 7
•u.
to
DAY. HOUR
20.0330
20.0430
20.0530
20.0630
20.0730
20.0830
20.0930
20.1030
20 . 11 30
20. 1230
20.1330
20 • 1 430
20 . 1 530
20. 1630
20*1730
20.1830
20.1930
20.2030
20.2130
20 * 2230
20.2330
21.0030
21.0130
21.0230
21 .0330
21 .0430
T
IN
53.079
53.211
53-344
53.477
53-609
53.741
53-873
54.006
54.138
54-271
-
-
-
54.404
54.538
54.672
54.806
54.941
55.079
55.213
55.347
55.482
55.618
55.753
55-888
56.922
0 T A L
K I L
FLUE
11*948
11.978
12.008
12.042
12.076
12.107
12.137
12-169
12.201
12.243
-
-
-'
12.274
12-303
1 2 . 329
12.355
12*382
12*409
12.434
12.462
1 2 - 489
12-517
12.545
12-574
12-602
S U L
0 M 0
REGEN
34.695
34*801
34.911
35*016
35.117
35.214
35.297
35.391
35.497
35.600
-
-
-
35.682
35.798
35.906
36.007
36.090
36.186
36.269
36.349
36-455
36.540
36.637
36.714
36.825
P H U
L S
FINES
3*865
3-872
3.880
3-888
3.895
3.901
3.908
3-914
3-920
3-926
-
-
-
3*931
3-937
3-945
3.953
3*961
3.969
3.976
3*983
3*990
4*001
4.01 1
4.018
4.030
R
IN-OUT
2*571
2*560
2.545
2.531
2.521
2-518
2.532
2.533
2.521
2.502
-
-
-
2-517
2*501
2.492
2.490
2*508
2*516
2*534
2*553
2*548
2*559
2*560
2*582
2*566
EQUIVALENT BURNT STONE
K I
FEED
3506*9
3514.8
3523-7
3530.4
3536.9
3549.5
3558.1
3564.6
3571.1
3580*2
3588-9
3594.0
3598.8
3608*5
3620.6
3633*0
3647* 1
3657*0
3665*6
3677.0
3688*0
3695.8
3707*9
3721-1
3729.2
3740.3
L 0 G R A
REMOVED
2838.9
2844.5
28 50 • 4
2856.1
2861 .4
2866.3
2870.7
2875.2
2879.4
2883-7
2889.3
2895.0
2898.7
2902*4
2906*1
29 1 2 * 3
29 1 8 * 4
2924*0
2929*6
2934*8
29 39 * 6
2944*4
2952*6
29 59 . 5
2965.2
2973.9
M S
IN-OUT
668.0
670.3
673-2
674.3
675.5
683.3
687.4
689.4
691.6
696*6
699.5
699.0
700.1
706.1
714*6
720*8
728.6
733-0
736.0
742.1
748.4
751 *4
755.4
761.7
764. 1
766.3
STONE CHANGE
21.0530
56.157
12-630
36.937
4.046
2*545
3748*0
P9R5.R
762. P
-------
I
U)
u>
21 .0630
21 .0730
21 .0830
21 .0930
21 . 1030
21 . 1 130
21 .1230
21 - 1330
21 .1430
21 • 1530
21 -1630
21.1730
21 .1830
21 .1930
21-2030
21 .2130
21.2230
21 .2330
22.0030
22.0130
22.0230
22.0330
22.0430
22.0530
22.0630
22.0730
22.0830
22.0930
22. 1030
22. 1 130
22. 1230
22. 1330
22. 1430
22- 1530
22. 1 630
22. 1730
56-291
56.424
56.562
56.696
56.830
56.965
57.101
57.235
57.371
57.507
57.641
57.777
57.91 1
58.044
58 . 1 78
58 • 3 1 3
58.448
58 • 58 3
58-717
58.852
58.986
59.120
59.253
59 . 388
59.522
59.655
59.789
59.924
60.058
60. 193
60.327
60.461
60.596
60.731
60.865
60.997
12.661
12.696
12.735
12.773
12.808
12.843
12.877
12.909
12.943
12.979
13.014
1 3 • 0 50
13*086
13.123
13. 160
13.193
13.227
13.263
13-300
13.342
13.384
13.423
13.461
1 3 . 49 3
13.530
13.561
13.599
13*638
13.676
13.714
13.752
13.797
13.842
13.889
13.937
13.984
37.036
37. 121
37.197
37.274
37.358
37.434
37.508
37.569
37-648
37.723
37.797
37-872
37.950
38.012
38-086
38-154
38-220
38-298
38.364
38-427
38 • 502
38-566
38.630
38 . 69 3
38.758
38.813
38.885
38.961
39 • 0 1 5
39.082
39 • 1 40
39.208
39.273
39.339
39.401
39 .448
4.057
4.073
4.080
4.093
4. 05
4. 14
4. 22
4. 30
4. 38
4. 47
4. 56
4. 65
4* 74
4-208
4.221
4.232
4.242
4.251
4.271
4-280
4.293
4.303
4.317
4.326
4.342
4.349
4.356
4.363
4.371
4.374
4.377
4.382
4.387
4.393
4.398
4.406
2.536
2.533
2.550
2.557
2.560
2.575
2.594
2.627
2.641
2.658
2.674
2.690
2.700
2.700
2.71 1
2.735
2.759
2.771
2.782
2.802
2-807
2.828
2.845
2.877
2.892
2.932
2.950
2.962
2.997
3.023
3.057
3.075
3.094
3- 1 10
3. 128
3. 159
3748.0
3748.0
3748-0
3755.4
3763.6
3771 .9
3778.8
3789.3
3799.3
3803.7
38 1 2 . 2
3821 .4
3831 .7
3841.4
3855.0
3863.5
3873.5
3882-8
3891 .8
3900.5
3910.5
3920.2
3929.5
39 3 7 . 7
3945.4
3953.9
3962.6
3970. 1
3977.0
3979.6
3979.6
3979-6
3979-6
3985-2
3992-9
4001 .9
2994.2
3007-8
3012-8
3022-9
3032-2
3038.3
3043.9
3049. 1
3054.3
3060.4
3066.5
3072.5
3078.4
3107.9
3116-7
3123-4
3130.2
3136- 1
3152-8
3 1 58 - 6
3 1 68 - 5
3175-2
3185-7
3191 .5
3204.5
3209.2
3213-7
3218-7
3223-7
3225.8
3228.0
3231 .2
3234.4
3238.1
3241 .8
3247.1
753.8
740.2
735.2
732.6
731 .4
733.6
734.9
740.2
745.0
743.3
745.7
748.9
753-2
733.5
738.4
740. 1
743*3
746.7
738.9
741.8
742.0
745. 1
743.8
746.2
740-9
744.7
748.9
751-4
753-3
753.7
751 -6
748.4
745-2
747. 1
751 - 1
754.7
-------
DAY.HOUR
APPENDIX C - TABLE VII
ANALYSIS OF SOLIDS REMOVED DURING RUN 6
TOTAL SULPHUR WT. PERCENT
GAS'R REGEN REGEN ELUTR BOILER BOILEI
CYCLONE FINES BACK FLUI
2.0730
2* 1600
2.2PI00
3.0130
3.1300
3.2000
4.0200
4* 1400
5-1030
5. 1800
6*0000
6* 1900
7.0800
7.2000
8.0000
8*0800
8*1600
9*0400
9 * 1 500
12.0500
12*1530
13*0300
13*1700
14*0500
14*1500
15*1800
16*0100
16*1000
16*1300
4.73
5.44
4.93
5.05
4.93
4.55
4. 17
-
-
4. 10
4*15
4.10
5.77
5*81
6. 15
6*35
••
5.67
4*71
4*16
4*42
4*51
4*84
3*27
3*32
4*35
4*43
3*85
3.35
3*55
-
3*42
5-47
5*11
2.91
2.56
3*40
3*87
2.74
2.75
3.36
3-29
4.96
4*29
4. 18
4.05
3.90
3*42
3*50
2*80
3*24
2.70,
2.39
2.34
2*96
•»
-
4.57
-
-
6*30
5*41
4.24
4*24
3*79
2.76
2.40
4*19
4*06
4*52
4.06
4.69
4*02
3*57
4*62
4*04
4*39
4*04
4*20
4.00
4.48
3*43
3*48
-
4.07
4.01
4.57
-
-
3.70
2*99
3*16
1.97
2.26
1.06
1.97
3.17
1*72
2.74
3.09
1.85
3.07
1.10
2.52
2.26
3«22
2.67
3*06
3.93
3*80
3*15
3.97
3.41
3.59
3*35
4. 19
-
-
-
-
4* 1 1
«•
-
-
4.00
3.73
1 .29
3*08
4*73
5.63
5*39
5*34
5*30
-
4*37
3*84
3*35
3.46
3*25
4*04
3*02
3*32
2.99
3*46
-
-
-
3*83
3*92
3* 74
3*82
3.80
4* 14
3*87
3*66
3-87
4*04
3*20
3*57
5*39
5*33
4*71
4*54
3*92
3.58
3.25
4. 14
3*95
4.55
4.23
2.67
3*21
3*50
4*48
-
-
3*01
3*35
3*55
3.7R
3*35
3*46
3*44
3*80
3*63
3*45
4*31
3*14
3*61
4*28
4*46
3*81
3-96
3-88
3-22
3.89
4-07
3.22
3.49
3.53
3.59
3*78
3*78
- 344 -
-------
APPENDIX C - TABLE VIII
ANALYSIS OF SOLIDS REMOVED DURING RUN 6
SULPHATE SULPHUR WT. PERCENT
DAY.HOUR 6ASVR REGEN REGEN ELUTR BOILER BOILER ELUTR
CYCLONE FINES BACK FLUE COARSE
2*0730
2*1600
2.2000
3.0130
3*1300
3*2000
4.0200
4. 1400
5. 1030
5. 1800
6.0000
6. 1900
7.0800
7.2000
8.0000
8.0800
8. 1630
9 .0400
9. 1500
12.0500
12. 1530
13.0200
13. 1700
14.0500
14. 1500
15. 1800
16.0100
16.1000
16.1300
-
0*27
0*21
0. 13
0-14
0*24
0.11
-
-
0. 1 1
0* 18
0.40
0.30
0.35
0.32
0.21
-
0*41
0.15
0.31
0.35
0*34
0.41
0. 19
0.50
0. 17
0. 10
0*18
0*12
-
-
1 .03
0.89
0.90
0.95
0.91
1 .02
0.96
0.90
0.83
1 .07
0.64
0.91
0* 44
0.62
0.87
0.89
.06 {
• 24
• 04
.27
.04
.67
• 48
.27
-
-
1.90
-
-
.29
• 31
• 15
• 31
.25
.47
.19
.89
.67
.92
.08
• 03
.03
.20
.38
.96
>*09
• 37
.29
.29
.45
• 68
• 38
-
.35
.33
.90
-
-
0.58
0.49
0.33
0.31
0.29
0. 13
0.32
0.37
0.48
0.14
0.34
0.23
0. 18
0.30
0.38
0.28
0.32
0.38
0.39
0.53
0*62
0*34
0.23
0.42
0.42
0*38
0.59
-
-
-
-
2.28
-
-
-
0.72
0.84
0.81
0.77
1*63
1 .26
1 .38
0.94
1.59
-
1 .28
1 .58
1 .42
0.95
0.79
3*08
1 .57
1 .40
1 .23
1*43
-
-
-
3.20
3.48
2.97
3.08
3.21
2.42
3.06
2.88
3.48
3.59
3.00
3.07
4.66
4.21
3.98
3.65
3.30
3*00
2.87
3.88
3.63
3. 77
3.59
2.38
3. 14
3.23
4.03
-
-
0. 9
0. 6
0. 1
0.20
0. 8
0. 3
0.21
0. 14
0.16
0.21
0.15
0.16
0. 17
0. 14
0.22
0.13
0. 18
0.20
0. 14
0.20
0.22
0.15
0.28
0. 19
0. 16
0*12
-
- 345 -
-------
APPENDIX C - TABLE IX
ANALYSIS OF SOLIDS REMOVED DURING RUN 6
TOTAL CARBON WT- PERCENT
DAY.HOUR
2.0730
2. 1600
2.2000
3.0130
3.1300
3*2000
4.0200
4.1400
5*1030
5*1800
6.0000
6.1900
7.0800
7.2000
8.0000
8.0800
8.1630
9.0400
9.1530
12.0500
12.1530
13.0200
13.1700
14.0500
14.1500
15.1800
16.0100
16*1000
16.1300
*S*R F
0. 19
0.18
0.23
0. 1 1
0.25
0.09
-
-
0.20
0.23
0.08
1.65
0.14
0.32
0.37
-
0.33
0.68
0.13
0.09
0.
0.08
0.
0.
0. 1 1
0.10
0*1 1
0.09
REGEN 1
(
™*
0.
0.04
0.04
0.05
0.
0.02
0*05
0. 15
0.04
0.04
0.16
0.
0.06
0.
0.07
0.
0.10
0.
0.08
0.
0.
0.
0.
0.
-
-
-
REGEN
:YCLONE
_
2.06
1.36
0.36
2.86
1.24
5.38
0.63
0.93
0.94
0.52
0.61
2.85
3.67
1.59
2.60
2.1 1
5.57
0.19
0.42
0.09
0.62
0.02
0.02
-
0*23
0.41
0*41
ELUTR B(
FINES
*
25.00
28.50
38.90
35.00
33* 10
45.00
35. 10
29.20
30.40
21.10
24.50
33.70
41*13
31 .60
42.70
46.60
36.20
17.70
21 .00
20.10
16.50
1 1.20
1 1.50
7.77
10.10
9.85
16*00
3ILER B
BACK
**
-
-
0. 14
-
-
-
0.45
0.51
0.77
0.34
0*20
0.08
0.25
0.32
0.48
-
0.58
0.08
0.14
0.28
0.16
0.
0.
0.04
0. 14
0.15
-
OILER 1
FLUE (
"
0.70
4.99
3.00
3.00
1.00
29.90
7.70
1 .30
6-37
6.04
3. 14
8.84
6-49
10*80
17.90
14.20
10.80
5. 78
6.70
3.25
4.98
3.32
3*44
1 .65
2.96
3.55
2.39
iLUTR
:OARSE
—
4.85
0.99
2.85
0.59
3.80
0.78
2.73
1 .19
2.04
3*46
0.55
8.37
3*23
1 .94
1.42
2. 17
7.75
2.34
3.74
2. 16
0.86
0.33
0.72
0*90
2.91
0.29
-
- 346 -
-------
APPENDIX C - TABLE X
Page 1 of 6
SOLIDS REMOVED DURING RUN 6* KG. (RAW DATA)
DAY-HOUR GAS'R REGEN REGEN ELUTR BOILER BOILER ELUTR
CYCLONE FINES BACK FLUE COARSE
1
2
2
2
2
0.P107
0.2352
.01 IB
.0240
.0500
.0655
. 09 30
. 1 530
. 1800
. 1845
2000
0440
0835
0900
1200
2.1315
?.1545
2.1700
2.1945
2.2235
3.0200
3.0450
3.0545
3.0745
3*0800
3.0930
3.1615
3.1750
3.1800
3.2000
3-2300
3.2330
4.0445
4.0730
4.1030
4.1400
4*1740
4.1945
4.2315
5.0100
7.94
6. 12
16.78
16.33
16.33
14.97
1 1 .79
16.33
1 5.42
13.15
13*61
15.42
12.70
15.42
5.90
0.68
-
0.91
.81
• 81
• 59
3.86
.81
.70
.59
3-63
6. 12
5.67
5-90
7.71
5.90
8.85
9.75
-
9.98
8.62
9*53
9*75
10.89
4.08
3*40
1 .81
6*80
9.53
1 .36
6.80
1 .36
8.16
0.23
-
-
0.23
0.68
0.23
0.91
2.27
0.68
0.23
0*23
*
2.27
2.49
1.13
0.91
0.91
1 • 13
0.45
1 *36
0.45
1 .81
-
-
-
-
-
-
22.68
-
0. 1 1
0* 1 1
0. 1 1
-
-
-
-
0. 1 1
*
-
-
_
-
0. 1 1
0. 1 1
-
.
0.23
-
4.08
8
4
3
20
9
1
8
7
5
.62
.54
.40
.41
.53
.47
.85
.26
.90
5.44 0.34
4.54
4.76
2.27
5.56
2.49
7.94
5.44
2.72
2.72
3.63
4.99
2.72
4.08
2.27
3.63
3.29
- 347 -
-------
Page .? of 6
SOLIDS REMOVED DUR1NC RUN 6* KG. (RAW DATA>
DAY.HOUR GAS'R REGEN REGEN ELUTR BOILER BOILER ELUTR
CYCLONE FINES BACK FLUE COARSE
5.0300 - - 4.76 1.13 1.25 2.95
5.0745 - - 9.07 21.09 0.68 4-76
5.1200 - 7.71 13.15 0.34 0.57 1.81
5.1445 J.81 - 2.04 0.23 1-81 6.80
5-1800 14.29 - 10.21 0.45 -
5.2000 23.59 - 1.81 0.45 1.13 0.68
5.2145 10.43 ------
5.2200 - - 3.97 0.68 0.68 1.59
6-0000 - - 3.86 0.11 1.36 2.27
6.0200 - - 6.24 0.45 -
6.0230 10.66 ------
6.0400 - - ^ 7.71 0.45 2.49 3.18
6.0445 9.07 -
6.0600 - - 6.92 0.57 1.47 1.93
6.0800 - - 6.46 0.45 1.59 2.15
6.1000 - - 7.03 0.34 2.72 2.95
6.1200 9.53 - 8.62 0.34 1.81 1.81
6.1400 9.75 - 6.35 0.34 1.81 2.72
6.1450 12.70 ------
6.1500 7.48-
6-1530 10.43 ------
6.1600 7.71 - 10.43 0.45 L36 1.81
6.1630 16.33 ------
^•1800 - - 5.22 0.23 1.36 2.04
6-2000 - - 4.08 0.45 2.72 3.29
6.2200 - - 4.65 0.68 4-54 2.38
7.0000 11.11 - 10.43 0.79 5.22 3.29
7.0100 8.28 ------
7.0200 5.22 - 8.05 0.23 3»18 1•59
7.0300 5.44 ------
7.0415 4.20 - 6.92 0.68 2.72 2.27
7.0500 6.01-
7.0600 4.42 - 7.03 0.45 2.83 1.70
7.0700 4.20 ------
7.0800 4.88 3.18 7.37 0.68 2.49 1.59
7.1000 - - 7.03 0.45 1.59 2.04
7.113P) 7.37 ------
7.1200 - - 5.67 1.02 1.36 1.47
7.1400 - - 3.18 0.45 1.93 1.36
7.1430 21.77 ------
- 348 -
-------
Paae 3 of 6
SOLIDS REMOVED DURING RUN 6* KG. (RAW DATA)
DAY.HOUR GAS'R REGEN REGEN ELUTR BOILER BOILER ELUTR
CYCLONE FINES BACK FLUE COARSE
7. 1 600
7. 1P00
7.2000
7.2200
8.0000
8.0200
8.0400
8.0600
8.0R00
R. 1000
8. 1200
8. 1400
8. 1600
8.2000
9 .0000
9.0100
9.0400
9.0R00
9. 1000
9. 1400
9. 1600
9. 1 730
9.2000
10.2300
1
1
1
1
1
1
1
1
.01 45
.4150
.0600
.0700
.0915
. 1015
• 1 100
• 1200
• 1 300
• 1 400
. 1600
.1730
.2000
.2200
.2300
2-0100
-
-
-
-
2.61
-
-
-
2.95
-
-
-
1 1 .79
-
-
16.33
-
-
-
-
-
-
-
-
-
12.70
-
13.15
9.75
8.14
5.88
-
5.88
3.61
0.21
-
-
-
-
9.07
3. 18
5.44
2.72
1.36
2.61
2.49
1 .36
1 .59
1 .59
1 .47
1.36
2.04
3.18
2.61
2.72
4.54
3.63
1 .36
1*13
4.54
0.45
3.97
2.27
10.43
7.26
16.78
20.87
-
8.28
6.80
11.79
1 1 .34
4.54
6.58
9.07
1.36
0.45
1.13
1 .02
0.91
0.34
0.68
0.34
0.23
-
0.23
0.23
0.23
0.45
0.91
0.91
0.68
0.45
0.91
0^45
0. 1 1
0.34
1 .59
1 . 13
1.13
0.68
-
0*34
0.45
0.23
0.45
0.23
0.91
0.68
1.59
1.13
1 .36
2.61
2.72
3. 18
2.27
3.29
7.71
2.83
1 .81
1 .47
1.11
1 .59
—
-
-
1 4.06
3.63
2.15
2.04
1 .47
-
0.45
-
-
-
-
-
-
-
1 .36
0.91
0.45
2.72
1.36
0.79
1 .47
1 .36
1 .81
1 .25
3. 18
2.27
0.91
1.13
0.91
0.91
1 .70
2.27
2.27
4.99
0.79
0.91
0.68
-
2.04
12.70
2.72
4.08
-
3« 18
1 .81
2-27
2.27
2.49
8-62
1 .81
1.81
- 349 -
-------
Page 4 of 6
SOLIDS REMOVED DURING RUN 6* KG. (RAW DATA)
DAY.HOUR GAS'R REGEN REGEN ELUTR BOILER BOILER ELUTR
CYCLONE FINES BACK FLUE COARSE
12.0200
12*0400
12.0600
12.0700
12. 1000
12.1200
12.1300
1 2 • 1 400
12*1430
12.1500
12.1600
12.1700
12.1800
12.1900
12.2000
12.2200
13*0001
13.0200
13.0400
13*0600
13.0800
13*1000
13.1200
13.1300
13*1400
13*1600
13*1645
13* 1800
13.2000
13*2200
14.0000
14.0200
14*0400
14.0600
14.0800
14.1100
14. 1430
14.1800
14. 1830
14*2300
-
15.88
5.44
-
-
9.07
7.26
4.54
-
8*16
3*18
2.72
3.18
2.27
2.27
6.80
4.99
-
-
-
-
*
-
•*
-
-
10.43
2.72
-
•»
-
-
-
-
-
-
-
12.70
1 1 .79
-
8*62
5.90
18.14
7.62
27.22
0*68
0.91
1.36
0.45
0*91
0*45
2.49
2.72
1 .36
2.27
1.93
4.31
3. 18
2.27
4.08
26.08 0*91 2.04 2.27
16.33 0.45 0.91 1.81
17.69
12.70
1 1 .34
9.07
13.61
9*98
20*87
21*21
16*78
-
9*53
2*72
0*45
1. 13
4*54
9*07
8*62
9*98
9*98
10.21
10.21
19.96
4.08
12.70
0*68
0*45
0*45
0.91
0.45
0.45
0.45
0.45
0*34
-
0.45
0.45
-
0.45
0.45
0.23
0.45
-
0.45
0.91
-
2.72
0.91
0.91
1.36
0.45
0.68
5.22
4*54
3.27
2.27
1 .02
2.72
4*31
1 .36
4.54
3* 18
6*35
5.90
5.44
4.08
4.08
4*08
3.63
4*54
- •
4*08
5*90
3.63
1.59
1.81
6.35
3. 18
2.36
1.81
2.27
1 .81
2.72
0.91
2.72
-
• 8
• 8
• 8
.8
.8
.8
.36
2.04
3* 18
2.72
3*63
19.96 0.79 6*12
5.90
- 350 -
-------
SOLIDS REMOVED DURING RUN 6* KG. (RAW DATA)
DAY.HOUR GAS'R REGEN
15.0200
15.0530
15-0700
15.0800
15.1000
15.1400
15.1800
15.2200
16.0100
16.0400
16.0700
16.1000
16.1400 29 • 48
16.1600 27.22
16.1700 14.06
16.1730 14.06
16.1900 14.51
16.2000 14.51
16.2040 15*42
16.2300
17.0200
17.0500
17.0700
17.0800
17.1000
17.1200
18.0600
18.0800
18.1000
18.1800
18.2145
19.0030
19.0400
19.0600
19.0800
19.1000
19.1200
19.1400
19.1600
19.1800
REGEN
CYCLONE
14.97
2.49
-
3.52
2.27
10.89
13*61
14*29
11.34
10.43
10*43
9*98
12.70
12.70
10.89
7*26
3.18
2.83
-
3*63
2.72
1.81
2.83
0.45
-.
-
-
1*36
13*61
0.45
-
0.23
0.1 1
-
0.23
-
ELUTR
FINES
0.34
-
-
0*23
0*45
0.45
1 .81
0*68
0*45
0*68
0*57
0*68
0.91
0.68
•to
0.68
0.57
-
0* 1 1
-
0*1 1
0*11
0*11
-
-
-
-
**
0*45
0.45
0*23
-
-
0*45
-
0.23
-
BOILER
BACK
14*51
35*15
4*54
4*31
7*71
7.94
6.80
4*76
5*67
6*35
9*53
8*16
12*70
12*25
5*90
4*76
13*15
24.49
18*60
7.94
14*74
14*29
-
11*57
-
-
-
0*68
0*45
-
-
•»
3*29
2*95
3*40
4.31
BOILER
FLUE
6. 12
7.26
-
2.49
8.62
5.22
4.08
3. 18
3.86
2.83
2.72
5.44
4.99
4.08
1 .81
2.27
3*40
4.31
-
4.54
7.48
3*18
-
8*39
1 . 13
174. 18
65.77
1 .81
5.44
4. 54
5.90
6. 12
3*63
3.40
3*63
3*63
Page 5 of 6
ELUTR
COARSE
- 351 -
-------
Page 6 of 6
SOLIDS REMOVED DURING RUN 6* KG. (RAW DATA)
DAY.HOUR GAS'R REGEN REGEN ELUTR BOILER BOILER ELUTR
CYCLONE FINES BACK FLUE COARSE
19.2000
19.2200
20.0000
20.0200
20*0400
20*0600
20*0800
20. 1030
20*1230
20.1430
20.1730
20*1930
20.2200
21 .0030
21*0200
21 *0400
21 .0600
21 .0800
21 * 1000
21 .11 30
21*1200
21.1230
21 .1430
21 .1700
21 .1930
21.2030
21.2200
21.2245
22*0045
22.0245
22.0445
22.0645
22.0830
22.1030
22*1230
22* 1430
22.1700
22.1830
22.2000
29.0000
-
-
-
-
-
«•
-
-
-
*
-
•»
-
-
-
. -
-
•*
8.85
4.99
-
3.86
-
-
-
-
24.04
-
-
1 L34
4.08
3.63
7.71
-
-
-
-
-
-
-
30.0000
3.63
3.63
3.52
2.15
3*52
3*86
2*72
3*63
2*49
2*27
2*49
2*83
4.42
2. 15
2*49
2.49
2.72
1.36
1. 13
5*22
5.90
4*54
5.90
4. 54
2.27
2*04
4.76
1.81
0.68
3357 '
0.23
.36
• 25
.70
.59
• 59
2.27
3.63
3.40
7.48
6.80
3.63
4.54
7.26
5.90
3.18
10*43
4.76
6*58
8. 16
9*98
11.79
11*34
6.80
11.79
8.16
8.62
10.89
8* 16
5*44
7.14
2*72
4.54
7.82
9.07
0.45
0.23
0.45
0.23
0.23
0.23
0.23
0*34
0.11
0*23
0.23
0.23
0* 1 1
0. 1 1
0. 1 1
0.45
0.45
0*34
0.23
-
0.11
-
1.02
—
0.68
•
0.45
-
0.23
0.23
0*23
-
0.1 1
-
0.
4.54
1 .81
4-54
3- 74
5.78
7.26
6.24
4.54
3.18
2.27
2.49
6.58
6.12
3*40
4.65
6.12
11.79
4*08
3*18
2.49
1.13
-
2.61
1.02
1.13
0*91
0.91
1.81
1.13
0.68
1.36
0.45
0.91
-
0.68
- 352 -
-------
APPENDIX C - TABLE XI
STOX'F FFED SAMPLES. RUN 6
SIEVE S1ZF IN MICRONS
SAMPLE
NUMPER
DAY- 320-3 2800
TIME 2800 1 400
1 /:P.M
1 180
1 180
850
8 50
6 P."
250 .
1 sn
1 Pi?.
„.,
V.T. PERCENT.
50471
50416
50428
50484
- 50444
50503
50417
50417
50515
50559
50514
50417
5^569
50417
50618
5P627
50661
53670
2.P730
3- 1309.
3.2000
5. 1800
5. 1030
6. 1900
6.2345
7.0845
7.2003
7.2359
7.0800
7. 1000
8 .0800
12.^500
12. 1530
1 3.0200
1 3- 1700
14.R500
.0
.0
.0
.0
.0
.0
.0
• 0 •
-0
.0
•0
• f)
.0
•0
.0
.0
.0
.0
15.
3£.
26.
21 .
25.
16.
9.
:23.
• 6-
5.
6.
2.
6.
23.
19.
25.
19.
15.
6 22. B-
1 22. 1
7
i
j
4
o
4
T
7
1
6
o
0
4
O
9. 1
8.3
9.7
4.8
£?. 1
8.0
5.8
6.0
4,8
3.8
4.3
7.3
5.9
9.8
9 17.1
5 13.7
34-4
33.3
35.7
38.9
36.3
31 .4
28. C
36.0
33.9
36.6
32.1
36.4
28.7
34.5
30. 1
33. 1
38.6
30.4
20.8
1 1 .2
11.7
13.7
11.4
18. 1
20.6
16.4
18.2
19.8
17.9
•21 .8
17.1
14.6
18*4
12.1
J3.9
23-6
9.8
.0
5.0
5.7
5.2
14.5
24.7
4.9
11.6
9. 1
1 4 . 9-
12.3
16.9
8.3
12.2
7*5
8.5
1 4. 1
.0
.0
.8
1 .2
1 .1
3«0
4. 1
.5
2.3
1.4
3. 1
1.5
3.7
1.3
1.4
1.2
•1.2
1.5
. 1
.0
. 1
• 3
. 4
1.1
1.5
.2
.8
.4
.9
.7
1.2
.5
.8
.3
.3
.5
.2
.3
.°?
• 8
.9
.6
1 .8
.6
.8
.8
1 • 1
.9
1.2
. 7
1.3
• 3
.5
. 7
-------
ui
in
APPENDIX C - TABLE
RUN 6
GA5UFIKR «JKD SAMP
SIEVE SIZE IN MI
XII
SAMPLE
MUMPER
DA Y - 3 2 £•'• P. 2 « ft P
TIME" 2>'??'
£2
/
15C.
1 50 " 1'Vfi
h'T. PERCENT.
5P473
5P4P.5
5P 41 1
53414
5W 429
50438
50421
5PM38
50445
50477
50436
5B6P.5
53496
53516
5P 5 1 0
5^584
50551
5P661
5^571
5?, 5 7?!
50584
53592
5^614
5^623
5^)659
5?. 6 68
5*3633
5^649
5PI646
5^678
5P683
5*695
507P0
2. 16flP
2.2RPIP
3.#P»3R
3. 133*5-
3.2RRP
4. 1 4PP
4.02P.O
4. 1 4Pltf
5. K13P
5. 1800
5.2359
6* 05P0
6* 19r?0
7.2'^P
7.P3PP
7. 1530
7.2359
P.R8PIP
8« 1 63P
9.fV!r'~n
9. 1 53d
9.?'*-3P
12- 1530
13* PPPfl
3. 1 7flpi
4 • flSPP
4. 1 5P.P
5. 1POO
6 • P 1 0 fl
6. if' 30.
.16. 23PQ
21-1 4««?
P2- IPHH
. 1
f\ t
• » f {
f\ >
• O
• yt
. 1
.7
• P
.f-'
.n
.0
• B
.«
.?
• 1
• 0
18.9
>«.S
*?• 5
4.4
3.0
2.0
4.8
2.7
3.7
3.2
5.?,
3.9
2.^
^..8
4. 1
10.7
.1 13.7
. 1
.0
• fl
.n
.w
• o
• 0
11.6
2.4
9-3
I 1 .0
1 P. 2
7.1
13.4
. O 21.4
.0
.ft
.0
.('
.0 1
.0 1
. n i
• 6 1
12.3
|4.4
1 4.R
3-4
4 . 4
1 .8
2-5
4.9
16.5
13. 1
15.4
14.8
13. 7
1.3.9
15.6
14.7
15.7
16-" 4
15.9
15.7
15.1
14.3
15.5
13.8
16.3
14.5
15.5
26.4
1 4.P!
13.2
28.5
1^.8
7.3
14.6
15.6
16.7
15. 1
16. 1
14.3
15-1
26.7
. 33- P
". 27.6
3^.S
' "32.9
3^*. 3
32-5
33.3
32.3
•34.2
34 . l
34.6
31.5
33*5
3g.Pi
33.8
34.0
3/1. 8
33-3
33.3
f?? • 9
33.5
32- P
29 . 1
31 .7
3L3
3^.8
3>r. . «
31 .5 r
28-6
32.0
31.1
se- • v
P3.P
2P.3
~ 1 9 . 5
PP5 . r.
24.2
25-3
26.6
23.7
28.4
?4.R
25.3
24.6
25.8
25.8
27. P
24. 4
28.9
P^6 . 7
26. 1
P6.4
pr. . 3
23.7
29. R
PB-5
25-1
P7.P!
P6-3
24. 1
23-9
26.9
23-4
25.?
24.9
2P.6
IP.
~!0.~
13.
13-
15.
1 >»•
1 1 •
1 1 .
1 1 •
11-
9.
13.
13.
15.
1 1 .
12.
IP.
14.
12.
14.
12.
14.
I/,.
14.
IP.
15.
14.
IP.
1 5-
13-
17.
16.
21.
9
8 •
3
5"
5
9
9
7
6
{.j
9
PI
3
B
7
6
3
1
4
9
8
6
/4
P[
2
9
9
j=t
j
9
6
7
/•
+ ?•
• . i
^.P
.a
.2
• Pi
.0
. 1
.«
.0
. ja
.f»
.2
• n
.«
.0
.0
. l
.(?,
• B
.!?
.R
• 1
.0
.0
. 1
. 1
.;>
• R
. 1
.?•
• t .'.•
.P
.f-i
. f.
?« 6
. 1
• Fl.
• H
.P
.n
.p
.p.
. r*
• fl
.«
.«
. 1
.P
.T.
. 1
.n
.f! -
.0
• P.
.P
. j>
.0
.r.
• 'j F
.0
• Cl
. l
.a
.n
. p-
. J
• .•*:
.P
• f l
.«
* t"-^
• ft
. i
• 1
.(?.
. 0
.0?
.f/,
.0
• 3
. P
.0
. 1
.0
• 1
.P
.P)
••2
.P
.J=5
.f!
• 1
. 1
• P
. 1
.0
t
• J
r*
• t'-
-------
CO
Ul
APPENDIX C - TABLE XIII
RUN 6
REGENERATOR DRAIN .SAMPLES
SIEVE SIZE Irt M1CPONS
SAMPLE
Nl.'MI-ER
DAY- 32(-''P . 2B90
1 1P.O
"59
6on
fW
25£
150 '
15f.
urn
K!T. PERCENT-
5« 4 72
50474
5-3413
5R429
50431
50437
59447
504RP!
5f:4«9
5C16H1
59 499
5P51 1
53 5 1 7
5? 554
50564
5?- 57 3
59579-
59593
59 58 5
50 6 1 f'<
59619
5 n ft 56
57:665
50634
5 "'641
b9 69 4
'59791
2.P733
2.
3-
3-
3-
4.
5.
5.
5.
6-
6-
7.
7.
7.
3-
8.
9-
9.
9-
12.
1 3»
13-
14.
1 4.
15.
21 •
22.
20 on
fUfl?-
1390
2009
1 490
1930
1899
2359
'•55?™
1999
9R99
2900
2359
9399
1 63?i
f * j* t~*t r^i
*^ ^> o / ~i
1530
1532
02 '-9
1 / r* C-*
959'j
15S0
inr-n
r/!99
incn
. i
. i
• i
- 1
.0
. l
.0
•P
• 1
.(•'I
»9
• 0
.n
. i
.R
.PI
.0
.9
. 1
• P'
. '•':
•?•:
.?•
• '?
• 1
• 7;
• J
21 .5
1F5.6
14.7
14.3
14.°
14.9
22.9
12.5
10- 3
9 .9
IP. 9
11.4
11.9
2.4
12. 1
. 4
1?'. 7
1 2 . 2
11.5
13-3
13-9
12. 1
11.6
10.9
12-3
1 1 .3.
16-*
1ft. 2
1 4 • 4
13.3
1 4.9
13. S
14.6.
12.6'
14. 1
12-5
1 1 .8
13.2
13.2
14.2
16- 1
1 4.2
1.4
12.9
14-3
14.6
14.9
15-4
1 TT9*
13.3
1 3 . 4
14.3
13.9
11-1
31 • 6
30.5
23.5
29 . 8
29.5
31 .7
27. 6
31 .#
30- 1
31 .9
3r>- 1
23. PI
31 .2
38.6
32-2
5.4
31 .5
31 -^
32-9
29 . 6
29 • 7
29 . 2
3? • 1.
32.3
2S -G
2'; .8
22. 7
19-7
2T- • 3
2fi -4
^ ^ T*i
<< .> . •• >
2 4 . 5
24. 1
22.5
25.5
26.6
25.4
25.P
27.2
25.6
32. f-
27.2
9.7
27.9
23 . 5
27.6
25. 1
25.2
2 ft . 6
24.2
37- -6
23.5
24. -f
2?. 6
10.6
14.6
21.3
18.1
17.fi
14.6
13-P!
16. n
19.5
2M « 4
19.4
P4.2
16.7
1 0 . 5
1 4.9
17.6
16.6
13.9
13-2
16.3
15-6
17.7
2i" • 3
1 : v . 4
2'?- 8
2 Pi . :5
2/i.9
-2
1 .1
1 . 1
.5
.3
• £
• 3
.2
-5
.6
*6
• 8
.3
.2
.2
16-9
.2
• '/.'
. 1
• 3
. 1
.5
• f '•
• 2 • n
C'
1 -2
i .3
.9
. 3
.2
. 1
. 1
."
. 1
f *
.2
. ?i
. 1
.2
. 1
. 1
.9
H « 5
• •?'
• 0
. ?*!
. 1
• 1
.r-1
. l
.3
. 1
*2
• 4
. i
. •*"*
.p
.':>-
. 3
B .•?,
. 1
• ^
. 1
. -
."
. 1
.r--
.'7
.2.
37. 1
• !
. 1
.r-
.0
• ^v
• i
*"?
• * •
. i
• ^.
-------
APPENDIX C - TABLE XIV
01
I
RUN 6
ELUTRIATOK COARSE SAMPLES
SIEVE SIZE IN MICRONS
SAMPLE
NUMBER
50401
50407
50471
50534
50426
50439
50442
50478
50487
50497
50513
50575
50582
50588
50596
50634
50613
50622
50645
50663
50 6 39
50643
50679
50696
DAY- 32PI0 280H
TIME 2800 • 1400
9t
3*
3.
3«
4.
4.
5.
5.
5.
6.
7.
8.
9*
9.
9.
12.
12.
13.
13.
14.
15.
16.
16-
21 .
Ofl«0
0130
1300
2000
02P0
1 400
1030
1800
2359
19P0
0800
1630
0400
1530
2030
0500
i 5f n
0200
1700
0500
1820
0 1 0n
10H0
R4^P!
.
•
.
.
.0
.1
.0
.0
• 0
.0
• 0
.0
.0
• ?>
.0
.0
.0
.0
.0
.0
.0
.0
. 1
6.5
3-5
6.5
6.5
7. 1
4.6
5.5
8.7
6.7
2. 1
7-3
3.8
2. 7
2.7
1.7
4-5
3-3
4.n
3-1
P. 9
4.6
5.8
6-3
4.0
1 400
1 180
1180
850
WT. PERCENT.
5 . J 13.3
4.2
7.1
7.P1
8. A
6.2
7.2
9.6
8.7
3.3
10.0
5.5
4« 4
14.6
2.6
6.0
4.8
5.1
4.5
10.6
6.2
8.0
9-0
5.5
13.5
18.9
19 .9
22.4
19.1
20.4
20.2
23.6
9.0
23.4
7.0
5.3
3-0
9.4
6.4
4.0
4.5
12.6
24.7
15.7
19.6
O^ ^ *7
1 4.2
850
600
14.4
17.2
20.9
P4.0
23.5
24. 1
24.2
20.2
26.6
13.0
25.2
24.3
23. 1
18. 1
12.8
22.3
21 .3
19.9
18.0
26. P
1? .8
P3-^
2?. 8
17.?
25P
46. 5
54.2
41 . 5
37.5
33-7
41 .0
32.2
23. 1
28.4
40.8
3?. 5
42. 1
42.3
28.8
25.0
36.?
43.0
44.?
44.8
OR ^5
33. ^
31 .7
37. 6 '
41 .6
250.
5.7
4.8
?_.2
1 .8
1 . 1
1 . 1
1 .0
1 .0
1 .3
6.6
1 . 1
2.8
4-3
4. 1
7.8
3-4
4.6
3-5
4.5
.5
4. 1
P. 8
1 .?
6. 1
150
1 .7
.6
.5
.7
• 4
. 4
.7
.0
.5
3.8
.2
.8
1 .6
?. 1
5.?
1 .9
?.?
1 .6
1 .9
.P
?.?
1 -6
. 3
2.P;
ip.P1
6.7
1 .8
P.P
?..4
3.3
3-5
g.6
17.3
4.2
PI .5
.3
3.8
6. 1
16.7
35.6
9. A
6«r<
7.3
1^.5
.?
1 5.3
7. 1
P. 3
9. 5
-------
C.A.F..B. RUN 6
2-OO
3-OO
6OO 7 OO 8OO
DAY HOUR
100 1200
FIG. CIS. SHEET. I
-------
C A F.B.RUN 6 (Contd )
Ul
00
I7-OO 18-00
DAY HOUR
19-00 20-00 2100 2200
FIG. CIS. SHEET.2.
-------
APPENDIX D
RUN 7
Operational Log, Inspection/ and Data
Page
Operational Log 36°
Inspection, Figures 1-24 37°
Data Table I Temperature and feed rates 392
II Gas flow rates 402
III Pressures 412
IV Desulphurisation Performance 422
V Gas Composition 432
VI Sulphur and Stone Cumulative 444
Balances
VII Analysis of Solids, Total 456
Sulphur
VIII Analysis of Solids, Sulphate 457
Sulphur
IX Analysis of Solids, Total 458
Carbon
X Analysis of Solids, Solids 459
Removed
XI Sieve Analysis, Stone Feed 463
XII " " Gasifier Bed 464
XIII " " Regenerator 465
Bed AC*
XIV " " Boiler Back 466
End
XV " " Elutriator 4b7
Coarse
XVI " " Cyclone Fines 468
Figure 25 - Chronological plot of unit performance
Figure 26 - Cyclone Fines size distribution, Sample 1 472
Figure 27 - " " " " Sample 2 473
- 359 -
-------
APPENDIX D
CAPB RUN 7
OPERATIONAL LOG
1Q.9.73 to 14.9.73 (Unit warm up)
Warm up commenced at 17.00 and the temperature was increased
steadily at 12°C per hour until 500°C and thereafter increased
at 20*C per hour bringing in kerosene at 700°C with a final
temperature of 85OeC. On 13.9.73 bed was added using
material retained from the gasifier at the shut down after
Run 6 and checks were made on circulation of bed material,
fluidisation and fines transfer, the latter needing some
adjustment for optimum performance.
On 14.9.73 the various systems were checked out, the fire
tube was removed from the boiler rear end and the unit
restarted on combusting conditions with kerosene. The first
attempt at gasification was unsuccessful with a momentary
main flame light up but followed soon afterwards by both main
flame and pilot flame failure. Four further trials were also
unsuccessful following the same pattern of main and pilot
flame failure.
15.9.73 (Day 1 of Gasification)
The main flame was established at 12.15 following adjustments
to the metering pumps and gas pilot flame. Conditions began
to line out with a stone feed of 13.6 kgs/h (30 Ibs/h) of
Denbighshire limestone (3200 - 600 micron range), 900°C gfsifier
temperature and 171 kgs/h (377 ]bs/h) fuel flow.
16.9.73 (Day 2)
The shooter for firing small quantities of the gasifier bed
into the left hand cyclone inlet was started up so that
regular short bursts of coarse material could be ejected into
the cyclone entrance with the purpose of minimising material
deposition in this critical area. The regenerator lower bed
pressure tapping blocked frequently and repeated rodding was
required to maintain its operation. Eventually the obstruct-
ion became so persistent that the regenerator bed depth
measurement was obtained by measuring the pressure drop
between the air inlet of the distributor and the gas space
above the bed and subtracting the distributor pressure drop
- 360 -
-------
from this measurement to obtain the bed depth. Samples of
bed material and dust from the various collection points
were taken at 16.OO.
The regenerator automatic bed transfer controller became
irregular but the trouble was found to be caused by a damaged
thermocouple cable from the regenerator which was repaired.
Some investigations were made into the effect of the fines
return to the gasifier and confirmed that the boiler SO2
level was increased by these injections into the gasifier.
17.9.73 (Day 3)
The unit ran smoothly and trials were made with two methods
of boiler SC>2 analysis. The hot gas cyclone sampling stream
introduced in Run 6 was retained for this run but comparisons
were needed with the system used in earlier runs which drew
a much smaller gas sample stream through the boiler door.
The pre-run 6 system was set up with the sample gases drawn
through a knock out vessel for water removal and a cotton
wool filter before passing to the sampling pump and analytical
instruments. For convenience of installation the sampling
point in the boiler door was 30 cms (11.8 ins), higher than
used in previous work and angled downwards by 10°. The
results of gas analysis from this point with the pre-run 6
system showed reasonably close agreement with the values
obtained with the hot cyclone sampling stream method. The
system was then returned to this latter method and a
further trial would be made later in the programme.
At 07.OO the stone feed rate was increased to approximately
twice stoichmetric so that the bed height could be built up
to 63.5 cms (25 ins) and then the feed rate was reduced to
about 11.8 kgs/h (26 Ibs/h).
18.9.73 (Day 4)
The regenerator temperature controller which operates the bed
transfer system was changed to control the regenerator to
gasifier transfer with the gasifier to regenerator transfer
controlled from the manually set timer. Some blockages were
experienced in the regenerator fines return system, the
shooter delivery pipe and in the left hand cyclone fines
return system but all were cleared without problems.
Samples of bed material and dust from the various collection
points were taken at 08.OO and at 12.OO the gasifier temper-
ature was lowered to 880"C by increasing the flue gas rate
and at 20.3O conditions were lined out smoothly.
- 361 -
-------
19.9.73 (Day 5)
AT O2.0O a further set of samples was taken at the lower
gasifier temperature with approximately the same limestone
feed rate, bed depths and fuel flow. The gasifier temper-
ature was then increased to 920°C and at 13.00 a further set
of samples was taken with approximately constant limestone
feed, bed depth and fuel flows.
The unit ran smoothly without any major problems and as
usual maintained a very steady set of conditions. At 16.3O
the limestone feed was cut back to about half stoichmetric
and the unit left to line out ready for the next data point.
At this stage there was no flue gas in use because of the
high heat removal rate from the water tubes in the gasifier
bed - about 13.8 kwatts (47,OOO BTU/h).
2O.9.73 (Day 6)
Some investigations were made into the effect of small
changes in the air rate to the regenerator. First of all
the rate was increased in small steps to find a maximum 802
removal rate. Within the short term it was found that the
actual S02 removal was about constant over about 8.5 m3/h
(5 cfm) air rate change. The investigation was complicated
by the change in bed circulation rate inherent in air rate
changes which in turn changed pulser frequency and hence the
quantity of nitrogen introduced into the regenerator offgas.
At 06.30 further bed material and dust samples were collected
and the flue gas reintroduced to lower the gasifier bed
temperature back to 880°C and it was observed that the boiler
S02 level increased from 350 ppm to 43O ppm corresponding
fairly exactly with this temperature change. Some problems
were encountered with leaks on the chimney stack top washer
pump which was then shut off for repair and some blockages
were experienced in the fines return from the left hand
cyclone. The shooter controller was adjusted to reduce the
quantity of material delivered at each operation because of
the possible danger of flooding the cyclone return handling
system.
At 18.OO a set of bed material and dust samples was taken
with the gasifier at 880°C and then the gasifier temperature
was increased to 92O"C again to determine if the previous
effect on SO2 concentration of a 40"C change in gasifier
temperature could be repeated but the level did not return
back to 350 ppm.
- 362 .-
-------
At 23.OO the water flow in the front bed cooling tube
decreased sufficiently to allow the formation of superheated
steam at 64O°C but the water outlet temperature returned to
75°C when the water flow was increased.
21.9.73 (Day 7)
Preparations were made to feed the narrow cut Denbighshire
stone (2180 - 300 micron range) and before the change was
made bed material and dust samples were collected at 04.00.
At 06.25 the narrow cut Denbighshire stone feed was started
and while conditions were lining out further tests were made
with the earlier sampling system on the boiler i.e. pre Run 6
system using the identical sampling point in the earlier
runs. The initial result of this test showed a nearly zero
ppm SO2 level in the boiler. It was then noticed that the
sampling hole which was situated in the centre of the boiler
door was obstructed by a large deposit of red hot lime and
after this was removed, the gas analysis using the Wostoff
analyser showed 11O ppm SO2- Draeger tube tests showed
140 ppm upstream of the cotton wool filter in the sample
line and 40 ppm downstream of this filter with the Wostoff
SO2 analyser reading 70 ppm having gradually drifted down
from the 11O ppm initial level. Further trials were made
on the S02 sampling system throughout this day using five
methods for analysis.
(a) Pre-run 6 configuration sampling from boiler door
centre point.
(b) Pre-run 6 configuration except sample taken from the
angled hole 30 cms (11.8 ins) above the boiler door
centre point.
(c) Techniques (a) and (b) above but with a through bleed
of gas from which a sample was drawn for analysis.
(d) The hot cyclone with continuous bleed as installed in
Run 6.
(e) Technique (d) above but with cyclone outlet sealed off.
The results of this work showed that (a) and (b) gave similar
results with SO2 levels below 10O ppm - there being some
variation depending upon the dampness of the cotton wool
filter in the line. The results of analysis with technique
(b) did not agree with the Day 3 trial earlier in this run
and could be explained by there being less lime deposits in
this sample tube on Day 3 due to the small number of hours
run at that time. Trials with technique (c) gave increased
S02 levels from less than 1OO ppm to about 3OO ppm.
- 363 -
-------
During the day the sampling system was changed to technique
(d) periodically to check the datum case which was averaging
500 ppm. A temperature of 1150°C at the entry of the gas
sample stream into the tube through the boiler door hot face
was measured by inserting a thermocouple through the sample
tube.
At 15.30 technique (e) was tried and an initial S02 level
of 260 ppm was indicated followed by a gradual drop to
70 ppm over a period of 4O minutes. The analysis was then
returned to technique (d).
22.9.73 (Day 8)
Some tests were made upon the effect of increasing the air
to the fuel injectors from 8.5 m3/h (5 cfm) per injector to
17 m3/h (1O cfm) and the result of this was to marginally
increase the boiler SO2 level. The gasifier space pressure
had reached 6.3 kPa (25.5 ins) water gauge at 05.OO and before
burning out the carbon/samples of bed material and dust were
taken to assess the .performance of the narrow cut Denbigh-
shire stone.
At 09.30 the bed sulphation was commenced and proceeded
quite normally being completed in about 20 minutes. The
carbon burn out procedure was then started and there was
some difficulty in achieving a reasonable gas flow rate
through the ducts partly caused by a joint on the blower
inlet which was found to have blown. There was some erratic
behaviour in the gasifier bed thermcouples particularly in
the top bed thermcouple which was getting cooled by the cold
recycle gas entering the lid. The water flow rate in the
bed cooling tubes was cut right back to less than 9 kgs/h
(19.8 Ibs/h) during this period with the slumped bed and low
water outlet temperatures were easily maintained.
It was apparent that the duct thermcouples were all heavily
coated with carbon because of their sluggish responses to
flow changes and observation through the boiler inspection
window showed the bifurcated duct thermcouple encrusted with
red hot material. At 14.15 the gasifier temperature had
dropped to 680"C and the unit was given a short period of
fluidisation with kerosene added to boost the bed temperature.
This caused the duct temperatures to rise rather rapidly
reaching 120O°C indicating that there was still carbon to
burn out. The bed was again slumped and burn out continued
until 16.00 when, with duct temperatures dropping the in it
was set on combusting conditions without undue duct temp-
erature increases.
- 364 -
-------
Both the cyclone drain legs were emptied to remove any
chunks of material which may have broken away during the
burn out procedure and then bed circulation was established
on combusting conditions. The unit was then shut down to
permit the cleaning of the boiler of accumulated lime.
23.9.73 (Day 9)
At 04.00 gasification was restarted and 27.2 kgs/h (59.9 Ibs/h)
stone feed supplied to build the bed but the response was
slow suggesting that the cyclones were not performing very
well. The left hand cyclone drain system was slow to build
pressure and at every operation there were sharp kicks in
the boiler S02 level suggesting that the butterfly sealing
valve was not shutting off tightly. Adjustments were made
to improve the valve seal by resetting the end stop on the
actuator. During this period of operation with the 2185 -
3OO micron size Denbighshire limestone there was no evidence
of any improvement in desulphurisation efficiency and the
losses with this fine stone were increased due to the bed
cyclone performance. The feed was therefore switched to
33OO - 6OO micron range Denbighshire stone at 13.OO hours.
At 18.3O some problems were encountered with the pneumatic
controllers on the fines return system for the left hand
cyclone and the drainage of this cyclone to the transfer
vessel was not running freely. The drain leg was rodded out
from above the cyclone and some lumps of material were
removed from the transfer vessel following this operation.
24.9.73 (Day 1O)
The shooter was reestablished to the left hand cyclone but
did not increase the temperatures in the cyclone transfer
vessel which would have been expected from past experience.
Then followed some problems with the automatic valve
controlling the flow of fine material back into the gasifier
and during this period whilst the valve controller was under
repair the fine material was returned to the gasifier in
slugs by manual operation of the return valve. These slugs
were sufficiently large to drop the gasifier temperature by
up to 20°C and kicks in the boiler SO2 level up to 1OO ppm
were associated with the return of each slug.
At 09.OO samples of bed material and dust were taken before
raising the gasifier bed depth. Soon after this some
problems arose with the fines return transfer pot outlet
pipe which blocked periodically indicating that lumps of
- 365 -
-------
material were still falling from the cyclone drain leg and
passing through the chunk trap installed in the transfer
vessel. The bed circulation through the regenerator became
a little slow and was improved by rodding through the
regenerator to gasifier transfer duct.
25.9.73 (Day 11)
The bed circulation system again showed some erratic
behaviour giving some problems in controlling the regenerator
temperature but was improved by increasing the pulse rate
on the nitrogen transfer controllers.
At 07.00 hours some samples of bed material and dust from
the various collection points were taken to determine the
effect of the increased gasifier bed depth whilst the unit
ran steadily throughout the day. At 17.00 further samples
were taken at nearly identical conditions before draining
out a quantity of the bed material so that the feedstock
could be changed to BCR 1359 (3200 - 60O micron range) with
the minimum quantity of Denbighshire stone remaining so
reducing the time delay in adequately purging the bed.
26.9.73 (Day 12)
The first eight hours of this period were spent in feeding
BCR 1359 limestone into the unit and withdrawing nearly
40O Ibs from the regenerator to improve the rate of change
of the bed to BCR 1359 specification.
At 12.00 some adjustments were made to the fines return
valve to try and slow down the rate of fines return and so
prevent large slugs of fines passing through into the
boiler. Some trouble was experienced with the fines return
system which blocked in the transfer line probably caused
by the higher proportion of coarse stone which prevented
the material forming into discrete slugs for good transport.
The regenerator cyclone which up to this point had been
returning its fines into the gasifier via the elutriator
was changed to drain into an external vessel for manual
emptying.
27.9.73 (Day 13)
The scrubber knock out chamber drain choked and water was
drawn into the recycle blower and into the recycle delivery
line. The system was drained off and a permanent bleed
made from the delivery pipe to prevent water being carried
- 366 -
-------
into the gasifier under fault conditions of the scrubber.
At O7.OO a set of bed material and dust samples was taken
before studying the effect of 920°C gasifier operation with
a high stone feed rate. The bed transfer system became
erratic again and high pulsing rates were necessary to keep
the regenerator temperature under control.
At 10.OO bed material and dust samples were collected before
halving the stone feed from twice stoichmetric. The
regenerator cyclone was not collecting much material which
suggested that the right hand cyclone was not draining
properly into the regenerator bed feed line due to either an
obstruction or else an unfavourable pressure balance situation
due to a high gasifier bed level and/or high cyclone entry
pressure drop. At 12.00 the gasifier bed level was lowered
to 53.5 cms (21 ins) to improve the pressure balance across
the right hand cyclone drain leg.
At 19.OO a further sample of bed material and dust samples
were taken before lowering the gasifier temperature. At
2O.OO the fines return system to the gasifier was blocked
off to investigate the unit performance without fines
return. The collected fines were drained into a bucket and
weighed and the two hour period of this operation yielded
18.2 kgs (4O Ibs) of fines.
28.9.73 (Day 14)
The period during which the fines were withdrawn from the
system did not make any significant difference upon the
boiler S02 level apart from giving a smoother trace. The
fines withdrawn during this test were then replaced into
the gasifier with an apparent improvement in the bed
circulation because the regenerator temperature dropped with
the pulse settings remaining constant.
The shooter to the left hand cyclone was restarted after
redding out and burning the carbon from the exit pipe in the
gasifier top space. At O8.OO the shooter stopped due to
some control failure which permitted the vessel to overfill
and subsequently the vessel would not empty. Some adjust-
ments were made during the day to reduce fines carry over
into the boiler by reducing the bleed rate in the cyclone
drain legs and the regenerator cyclone was returned to
external manual drain.
- 367 -
-------
At 16.00 further problems were encountered with the bed
transfer rate which required a fast pulsing rate to control
the regenerator temperature. At 2O.OO samples of bed
material and dust were collected.
29.9.73 (Day 15)
The early part of this day was concerned with investigating
the effect of various air flow rates upon the regenerator
SO2 release. The air rate to the regenerator was changed in
increments allowing the conditions to steady out between
changes. At 11.OO further samples were collected before
raising the regenerator temperature. These changes in air
flow and temperature in the regenerator were made in an
attempt to cut down the stone sulphur loading and with
35.5 m3/h (20.9 cfm) air flow to the regenerator the unit
was given time to settle before taking bed material and dust
samples at 17.45.
The regenerator air rate was then increased to 38 m3/h
(22.4 cfm) but the sulphur removal did not improve and there
was difficulty in holding the temperature. At 19.45 the
regenerator air rate was lowered to about 30.5 m3/h (17.9 cfm)
The elutriator fines return pipe to the gasifier blocked up
at 20.45 and it was successfully drilled out.
30.9.73 (Day 16)
Preparations were made to connect up the single fuel injector
which was positioned through the centre of the distributor.
Prior to switching the fuel to this injector a further set of
samples was taken at 15.OO.
At 15.15 the centre fuel injector containing six outlet holes
was pushed up into the gasifier so that the outlet centre
line was at the same height as the side wall fuel injector
hole centre i.e. 11.5 cms (4.5 ins) above the distributor
nozzle centres. Initially there was a high air pressure
through the injector but after some minutes the obstruction
partially cleared and the air pressure dropped to 75.8 kPa
(11 psi) for 13.6 nr/h (8 cfm) flow. The centre side wall
injector oil supply was diverted to the single injector at
17.20 and after levelling out without any obvious problems,
the left hand side wall injector supply was added at 19.40
and at 20.40 the total oil supply was fed through the bottom
injector. Air bleeds were left in the three side wall
injectors for cooling purposes.
- 368 -
-------
1.10.73 (Day 17)
Some trials were carried out on the effect of the single
fuel injector height and there was some uneveness in the
gasifier bed temperatures during this period. At 13.00
bed material and dust samples were collected. It was then
planned to make quick tests by raising the fuel injector
positions until a sharp deterioration in performance was
reached but after moving 1.3 cms (.5 ins) upwards the
injector jammed and could not be moved. Instead of this
injector position test the unit was lined out with a high
stone feed rate of 1% stoichmetric and at 18.OO bed material
and dust samples were collected before tests were made upon
the effect of raising the water cooled tubes in the bed.
At 19.1O the rear water tube was raised up about 2.5 cms
(1 in) with an immediate response in the water outlet
temperature which was held at 7O°C by increasing the flow
rate to 250 kgs/hr (55O Ibs/hr). At 2O.OO the rear water
tube was raised a further 2.5 cms (1 in) and the water outlet
temperature approached 100°C with 250 kgs/hr (550 Ibs/hr)
flow rate. There were fairly marked drops in the gasifier
bed temperatures at these changes in the water tube position.
During the previous 24 hours the gasifier space pressure had
risen quite sharply and at 21.30 had reached 6.7 kPa (27 ins
water gauge) which was near the maximum level recommended
for safe loading on the gasifier lid. It was therefore
agreed that the unit would be shut down by reducing the fuel
flow in steps of approximately 11.4 kgs/hr (25 Ibs/hr)
keeping the gasifier superficial velocity constant by lowering
the air rate to keep constant temperature but increasing the
flue gas to maintain constant velocity in the bed. A series
of step changes were made, each time adjusting the main
burner air rate to keep about 2% oxygen in the boiler flue
until at a flow of 82 kgs/hr (18O Ibs/hr) of fuel the flame
failure alarm came up and shut the unit down. This last
period of gasification was the longest achieved with this
pilot plant and cool down was made with nitrogen purges at
various locations to prevent carbon burning off so that some
measurements could be made of the carbon thickness after over
200 hours of continuous gasification.
- 369 -
-------
APPENDIX D
CAFB RUN 7
INSPECTION
Gasifier and Regenerator Refractory
The gasifier walls were generally blackened overall with a
thin layer of carbon deposited on the lower sections polished
by the action of the bed material. The carbon above the bed
close to the lid was up to 6 mm (.23 ins) thick with an
irregular surface and in some areas it had bridged across to
the underside of the lid and formed a joint to the refractory.
The vertical cracks in the gasifier side walls present before
this run had not deteriorated and had acquired the usual
deposition of carbon along the line of the crack. There was
one new crack which ran around the horizontal joint below the
top refractory lift i.e. 28 cms (11 ins) below the top face.
The concrete on the lid was generally good, again deposited
with carbon (fig D.I) on its exposed face about 6 mms (.23 ins)
thick. The insulation behind the hot face was cracked and in
some areas large pieces had fallen away.
The transfer passages to and from the gasifier were in
excellent condition without any cracks. The gas burner
quarl did not show any deterioration and unlike previous runs
the passage through the quarl was not heavily obstructed
although there were some deposition in the lower section.
The regenerator bore was clear of any obstruction and on the
wall at the top of the bore, well above the bed there were
1 cm (.4 ins) thick hard deposits of white fine material with
a smooth very light purple external surface. A piece of this
material was removed from the wall (fig. D.2). The cracks
evident before the run had not deteriorated significantly.
The silicon carbide ring inserted as a spacer to lower the
distributor was in good condition with some thin deposits on
its inner face. The ring was firmly fixed in place by a
mixture of fine and coarse material which had penetrated into
the annulus between the outside of the ring and the
refractory concrete hole into which it had been placed.
- 370 -
-------
Gasifier and Regenerator Penetrations
The thermocouples, fuel injections, pressure tappings and
drains were in good order throughout. Some of the bed
thermocouples showed a local thinning of approximately .5 mm
(.02 ins) on the 17 mm (.67 ins) diameter and in other areas
there were deposits of similar magnitude. There was a layer
of carbon deposited on the lid gas space thermocouple (fig. D.I)
which was typical of the other penetrations in the gas space
area. Part of the carbon had fallen away showing the thermo-
couple sheath beneath. Both the shooter tubes which
protruded through the wall in this area were blocked with
carbon, one tube had not been in use throughout the run and
the other tube had stopped some hours before the shut down.
The centre single fuel injector which passed through the
distributor was apparently clear although the pressure-flow
characteristic during operation suggested some obstruction.
There was a small deposit of carbon on the top of this
injector but this would not have influenced the fuel
distribution or pressure drop characteristic. The
regenerator penetrations were generally clean apart from the
deposit at the bottom of the pressure tapping (fig. D.3).
Cyclones
The left hand cyclone inlet was heavily obstructed with a
predominately carbon deposit around its entry (fig. D.4).
The open area of duct remaining represented about 29% of the
original area and at a point 4 cms (1.5 ins) from the entry
section the remaining area was 32% but after a further 2 cms
(.8 ins) the duct opened considerably to about 75% free area.
The deposit was very hard and firmly attached to the
refractory and analysis showed that it consisted of 8O - 85%
carbon with the balance of calcium and sulphur. The carbon
around the left cyclone entry was laid down with a corrugated
surface finish with the lines parallel to the entry duct.
The origin of the loose piece of carbon (fig. D.4) bridging
across the upper section is unknown but it may have fallen
from the lid when a sudden pressure rise was observed in the
gas space pressure near the termination of the run.
The right hand cyclone entry was heavily obstructed (fig. D.5)
and here the obstruction in the duct became greater away from
the entry section with a free area of 26% at the entry and
20% at a point of 4 cms (1.6 ins) into the duct. The deposit
was again very firmly attached to the refractory and became
lighter in colour away from the duct entry. The silicon
- 371 -
-------
carbide cyclone outlet tubes were cast into refractory
collars which were located on top of the cyclone bodies and
sealed with refractory cement. Unlike previous runs it was
not possible to lift off these collars and they were gently
cut away to show the inside of each cyclone immediately by
the entry duct. Here the gas would first strike the centre
tube before starting the downward vortex to enter the
outlet tube at the bottom. (Fig. D.6) and (fig. D.7) show the
left and right hand cyclone silicon carbide tubes were
reasonably clean at the face opposite the gas entry but then
acquired a heavy irregular deposit around the remaining area.
There is some indication that the left hand cyclone was a
little less obstructed and the shooter may have helped in
this area. The deposits on the cyclone walls were extremely
hard and strong and in some areas bridged across from the
outer face of the silicon carbide outlet tube to the wall of
the cyclone.
The left hand cyclone lower section was clear (fig. D.8) but
the right hand cyclone was completely obstructed in the
lower section by a build up of fine material with a complete
crust over the top about 55 cms above the cyclone drain
point. Beneath this crust there were other hard pieces with
the finer material filling up the remaining space. (Fig. D.9)
shows the drain after some of the fine material had been
removed to show up the crust formations attached to the
cyclone wall. Some of the crust had fallen away before the
photograph was taken. It is most likely that the right hand
cyclone was obstructed for a long period because the carbon
on the outlet tube (fig. D.10) did not show the vortex profile
of the left hand cyclone outlet (fig. D.ll) indicating the
swirling action of the outgoing gases produced by the correct
functioning of a cyclone.
The internal drain leg which branches off the vertical
external drain leg of the right hand cyclone to join the
gasifier to regenerator transfer line was blocked at one of
the bends between the cyclone bottom point and the bed
material transfer passage. This obstruction prevented
drainage and the cyclone then filled with material until the
level rose sufficiently to prevent any further deposition
and subsequently all the fine material passed straight out
of the cyclone.
The left hand cyclone internal drain leg which branches off
the vertical external drain leg to join the regenerator to
gasifier transfer duct was sealed off before this run by a
50.1 ran (2 in) diameter stainless steel tube placed in the
- 372 -
-------
cyclone drain leg. The tube was removed after the run and
there was an area of corrosion (fig. D.12) corresponding to
the entry pipe of the internal drain connection. There was
more severe thinning in the remaining material immediately
around this area. The inside surface of the tube was not
corroded indicating the corrosion was caused by gas coming
up the drain leg from the regenerator to gasifier transfer
line.
Gasifier and regenerator distributor
The gasifier distributor was in good condition with some
thin lime deposits on some nozzles, with 5 of the 192 holes
completely blocked, these nozzles were grouped near the
fines return pipe to the gasifier. There were 53 other
randomly placed nozzles which were partially blocked. The
refractory which was in good condition had a thin layer of
fine bed material in the defluidised zone below the nozzles
which protruded higher than earlier distributor designs.
The regenerator distributor was in good condition with one
or two areas having a thin deposit of fine material. All
the holes were quite clear (fig. D.13) apart from the centre
drain.
Bed Material
The gasifier was shut down without sulphation and (Fig. D.14)
shows the top of the bed after the lid was removed. The
carbon debris on the bed fell from the lid which was firmly
bonded to the gasifier upper wall by this carbon. The bed
material was free from large agglomerates and within the
depth of the bed some pieces of carbon were found about
2 cms (O.8 ins) across. The regenerator bed was free flowing
and without agglomerates.
Water cooling tubes
Two water cooled tubes 27 mm (1.O6 ins) outside diameter type
321 stainless steel were installed through the gasifier
distributor each with independent water cooling control
(fig. D.15). Initially they were to be placed in the
retracted position below the fluidised zone thus minimising
their possible heat pick up. Unfortunately due to some
accidental displacement, the front tube was slightly exposed
to the fluidised region of the bed and the results show that
this tube absorbed more heat than the rear tube.
The front tube which was not raised up from this displaced
position is shown in (fig. D.16) with the polished areas
- 373 -
-------
caused by local air impingement from local distributor
nozzles. The tube was slightly distorted after the test
and this may be due to a short term very high temperature
excursion when the water cooling rate fell low enough,
for the generation of steam. It is estimated that 60% of
the tube area had carbon-lime deposits less than .25 mm
(.01 ins) thick and 2% of the area was covered with deposits
less than .90 mm (.035 ins) thick, the remainder being clean,
The rear water tube which is shown in (fig. D.17) was moved
up into the fluid bed during the last day of the run with
the cooling rate maintained to prevent steam formation.
This tube was also slightly distorted from its original
shape but like the front tube remained free from leaks.
The material deposition was less marked due to the
cleaning action of the fluid bed and showed 20% of the area
deposited with material less than .25 mm (.035 ins) thick
and 5% covered with material less than .90 mm thick with the
remainder of the tube clean.
Bifurcated duct
The bifurcated duct between the gasifier cyclone outlet
and the burner was generally clear apart from carbon
deposits built up around the thermcouple and on the
refractory walls. (Fig. D.18) shows the hot gas duct with
carbon and lime deposits about 4 mm (.16 ins) at the top
wall of the duct, 12 ram (.47 ins) on the bottom and 8 mm
(.32 ins) on either side. The difference in the thickness
of the deposits arose during operation and burn out when
material may have dropped out of the gas stream.
Premix Section
The air premix section, installed between the bifurcated
duct and the burner, consists of an inner insulated pipe
with an annular gap through which the first stage air is
admitted. The inner stainless steel pipe, in contact with
the hot gas, was coated with carbon varying in thickness
from 7 mm (.28 ins) to 4 mm (.16 ins). The outer
steel shroud around the pipe insulation was heavily scaled
by local high temperatures at the leading edge close to the
mixing zone between the air and hot gas and in some areas
the scaled material had broken away (fig. D.19).
- 374 -
-------
Burner
(Fig. D.2O) shows the carbon/lime deposits in the burner
entry duct deposited around 60% of the duct periphery and
leaving 66% of the duct area open. The deposit was hard but
not firmly attached to the duct being retained by the
geometry of the section. This entry duct is supported by a
flange attached at the leading end to the burner body by a
stainless steel flange. This flange was cracked along a weld
line around approximately 40% of the periphery (fig. D.21)
and coincided with the deposited material in the entry duct
suggesting local temperature gradients due to shielding from
the deposits. The pilot burner was slightly coated with lime
but otherwise in good order.
Boiler and Stack
(Fig. D.22) shows the boiler after opening the rear door. All
the tube ends were coated with lime deposits and 45% of the
tubes were totally obstructed either by the thick layer of
material built up in front of the tube plate or in some
cases isolated tubes on the right and left hand side near
the top of the array were plugged. Generally the plugs
were hard and compacted, penetrating up to 10 cms (4 ins) into
the tube base. The final pass boiler tubes all contained a
thin coating of dust apart from one tube in an identical
position on each side which was almost obstructed. The
boiler corrugated fire tube had deposits of coarser material
laying along the bottom.
The refractory was generally reasonable with light brown
flaky deposits on the hot face at the end of the fire tube.
The bricks in this area had loosened at their joints and
will be rebuilt before the next run.
A total of 213 kgs (470 Ibs) of material was removed from
the boiler tubes, 121 kgs (267 Ibs) removed from the front
soot box, i.e. at the exit of the first tube pass and 161 kgs
(355 Ibs) removed from the area at the end of the flame tube.
The stack and cylcone were clear with 3.2 kgs (7 Ibs) of
material deposited in the collection zone at the bottom of
the stack.
Burner probe
The burner test probe was controlled at approximately 60O°C
by internal air cooling but there were circumstances when the
temperature dropped due to the failure of the automatic
- 375 -
-------
controller which permitted full flow of cooling air.
(Fig. D.23) shows the installed position of the tube with
the free end protruding into the main flame path and the
root of the tube shielded with the hot gas turning past it
to enter the first tube pass.
The side of the tube end facing the burner was lightly
covered with a hard tenacious white deposit varying from
0.5 mm (.02 ins) to 1.0 mm (.04 ins) thick and locally
pitted by particle impingement. The trailing side of this
end had a local brown fine deposit shown in (fig. D.24) with
the adjacent area covered with a O.25 mm (.01 ins) thick
soft white deposit which was easily removed. The root end
of the tube facing towards the boiler tube entries had one
light brown deposit 12.5 mm (5 ins) thick and 12 cms
(4.75 ins) long and on the opposite face there was a
similar deposit 40 cms (15.7 ins) long and 6 mm (.24 ins)
thick. The remainder of the root end was covered by a O.4 mm
(.16 ins) thick deposit which was fairly readily removed.
- 376 -
-------
Fig. D.I Gasifier Lid
- 377 -
-------
Fig. D.2 Deposit from regenerator top
Fig. D.3 Regenerator bottom view
- 378 -
-------
Fig. D.4 L.H. cyclone inlet
- 379 -
-------
Fig. D.5 R.H. cyclone inlet
- 380 -
-------
Fig. D.6 L.H. cyclone outlet tube in situ
Fig. D.7 R.H. cyclone outlet tube in situ
- 381 -
-------
Fig. D.8 L.H. cyclone
1
Fig. D.9 R.H. cyclone
- 382 -
-------
Fig. D.lO R.H. cyclone outlet
Fig. D.ll L.H. cyclone outlet
- 383 -
-------
CM
Fig. D.12 L.H. cyclone drain leg seal
Fig. D.13 Regenerator distributor
- 384 -
-------
Fig. D.14 Gasifier Bed
Fig. D.15 Gasifier cooling tubes
- 385 -
-------
Fig. D.16 Front cooling tube
Fig. D.17 Rear cooling tube
- 386 -
-------
"• • ' -«: • . , v ;
Fig. D.18 Bifurcated duct
Fig. D.19 Burner premix section
- 387 -
-------
Fig. D.2O Burner (rear view)
- 388 -
-------
Fig. D.21 Crack in burner flange
- 389 -
-------
Fig. D.22 Boiler back end
Fig. D.23 Boiler probe installation
- 390 -
-------
Fig. D.24 Boiler probe
- 391 -
-------
APPENDIX D - TABLE I
RUN 7: TEMPERATURES AND FEED RATES
PAGE 1 OF
DAY.HOUR TEMPERATURE* DEC. C*
GASIFIER RE6EN. RECYCLE
FEED RATE KG/HR
OIL STONE
.1230
• 1330
.1430
-1530
• 1630
.1730
.1830
.1930
.2030
.2130
.2230
.2330
2*0030
2.0130
2.0230
2.0330
2.0430
2.0530
2*0630
2*0730
2.0830
2.0930
2.1030
2*1 130
2*1230
2*1330
2. 1 430
2*1530
2.1630
2.1730
2.1830
2.1930
2*2030
2*2130
2.2230
2*2330
3.0030
3.0130
3.0230
3*0330
940.
905.
905.
890.
888.
898.
905*
892*
876*
884.
899.
907.
911*
894.
898.
894.
903.
901*
902*
898.
899.
896*
885*
895*
884.
894.
900*
900.
904*
905*
892.
892.
896*
891.
891*
884*
899.
882.
889.
886.
974.
1040.
1040.
1045.
1035.
1046*
1032.
1045*
1030*
1060.
1062*
1060.
1065*
1063.
1059.
1069.
1062.
1060.
1055.
1060.
1062*
1066.
1070.
1068*
1068*
1070.
1070.
1070*
1078*
1079*
1082.
1066*
1068*
1048*
1050.
1050*
1055*
1058*
1050*
1050.
62*
70.
70.
70.
68*
68*
68*
70.
74*
75*
69*
69*
69*
69*
69*
69*
68*
69*
68*
68*
64*
69.
67*
65*
64*
64*
64*
65*
64*
61*
61 .
66*
66.
65*
63*
62.
69*
63*
66*
63*
177.2
177.2
173.1
174*7
174.7
175.6
175.1
175.1
175.1
176*4
174*7
175*6
175.1
176.0
175.6
175.1
175.6
175.6
1 74.7
175.6
175.1
175*6
176*0
174*3
175*1
175*6
176*0
176.0
176.4
178.9
173*5
176.0
176*0
176*4
176*4
176.4
176.4
174.3
177.6
176*8
0.
0.
0.
2.3
15*0
16.3
9*5
10*9
10*9
10*4
10*0
10*4
13*2
14*5
12*7
15*4
17*2
18.6
19.1
19.1
18.6
17.2
20.0
18*6
20.9
18.6
10.9
13*2
14*5
14.1
1 1 .8
13.2
13.6
14.5
14.1
14.5
15.0
15.9
14.1
15.0
- 392 -
-------
RUN 7: TEMPERATURES AND FEED RATES
PAGE 2 OF 10
DAY.HOUR TEMPERATURE* DEG. C»
GASIFIER REGEN. RECYCLE
FEED RATE KG/HR
OIL STONE
3.0430
3-0530
3-0630
3.0730
3.0830
3.0930
3* 1030
3 • 1 1 30
3.1230
3. 1330
3* 1430
3. 1530
3* 1630
3. 1730
3. 1830
3.1930
3*2030
3.2130
3-2230
3.2330
4.0030
4.0)30
4.0230
4.0330
4.0430
4.0530
4.0630
4.0730
4.0830
4.0930
4* 1030
4- 1 130
4. 1230
4.1330
4. 1430
4.1530
4. 1630
4.1730
4. 1830
4. 1930
881 .
88! •
889.
885.
881.
883.
889.
883.
866.
883.
880.
873.
880.
876*
878.
880.
878-
888.
899.
892.
899.
899.
888.
890.
890.
892.
855.
895.
895.
890.
897.
892.
878.
881 .
885.
886.
886.
869.
880.
882.
1052.
1050.
1061 .
1060.
1060.
1064.
1060.
1061 •
1061 .
1061 .
1062.
1061 .
1062.
1060.
1060.
1062.
1063*
1062.
1061 •
1062.
1062*
1062.
1070.
1080.
1060.
1072.
1080.
1081 •
1082*
1077.
1065.
1066.
1065.
1066.
1060.
1064.
1068.
1068.
1069.
1072.
63.
69.
68.
58.
66.
68*
68*
69.
70.
68.
67.
67.
64.
64.
65.
64.
62.
60.
60.
60.
60*
60.
60.
60.
60.
60.
60.
60.
60.
60*
60.
60.
64.
65.
68.
69.
70.
66.
60.
60.
176.4
176.0
176.4
176.8
1 76.4
176.0
176.4
176.4
176.4
176.0
1 78.0
1 74.3
176.0
176.4
1 76*4
176.4
176.4
176.0
176.4
177.2
180.5
185.0
185.9
187.9
187.1
187.5
187.9
187.5
187.9
187.1
187.9
186.7
184.6
184.2
184.2
184.2
184.2
184.2
184.6
184.2
1 5.0
13.6
21 .3
23.6
25.9
24.0
22.2
24.5
32.2
31 .3
29.0
30.8
31-8
35.8
27.2
30.8
28.6
28.6
16.3
1 1 .8
10.9
12.2
13*2
1 1 .3
12.2
11.3
10.0
1 1 .3
14.1
1 1 .3
9.1
1 L3
1 1 *3
1 1 .3
12.2
10.9
10*0
13-2
14-5
13.2
- 393 -
-------
RUN 7: TEMPERATURES AND FEED RATES
PAGE 3 OF
DAY.HOUR TEMPERATURE* DEG. C.
GASIFIER REGEN. RECYCLE
FEED RATE KG/HR
OIL STONE
4.2030
4.2130
4.2230
4.2330
5.0030
5.0130
5.0230
5.0330
5.0430
5.0530
5.0630
5.0730
5.0830
5.0930
5. 1030
5.1 130
5.1230
5* 1330
5. 1430
5.1530
5. 1630
5. 1730
5 . 1 8 30
5.1930
5.2030
5.2130
5.2230
5.2330
6*0030
6.0130
6.0230
6.0330
6.0430
6.0530
6.0630
6.0730
6.0830
6*0930
6* 1030
6.1 130
882.
889.
885.
885.
887.
885.
908.
919.
922.
912.
917.
920.
918.
918.
920.
920.
920.
918.
917.
916.
915.
918.
925.
930.
926.
930.
930.
930.
930.
930.
928.
929.
925.
928.
929.
911.
912.
912.
920.
920.
1060.
1068*
1068.
1061 •
1065.
1072.
1062.
1075.
1064.
1064.
1060.
1064.
1074.
1071.
1069.
1070.
1075.
1069.
1073.
1068.
1070.
1068.
1070.
1069.
1065.
1066*
1062.
1061 «
1065.
1065.
1073.
1070.
1070.
1075.
1072.
1074.
1070.
1075.
1071.
1080.
60.
60.
60.
60.
55.
54.
45.
42.
42.
42*
42*
42*
42.
45.
46.
44.
40.
42.
42.
45.
45.
40.
44.
30.
40.
45.
45*
48.
48.
48.
48.
48.
48*
48.
48*
60.
60.
60.
60*
59.
185*0
184*2
185*9
184.6
185*0
185*0
185.5
184*6
185.0
186*3
189*6
190.4
190.8
190.8
190.4
190.4
190.4
190*8
190.4
190.0
190.0
190.0
190.4
190*0
189.6
190.4
190.0
190.0
190.0
190.4
191 .2
191 .6
191.6
192.5
192.0
191.6
192.0
192.0
191.6
191 .6
11-3
1 1 *R
13*2
12*2
12*2
12*2
14.5
14.5
14. 1
15.0
14.5
12.2
15.0
12.2
10.4
12.2
1 1 *8
12.7
12.7
1 3.2
13*6
1 1 .8
8*6
7.7
6*8
5.4
6*8
6*8
6*8
7* 3
8*2
W ^ fmt
7*3
* w v
7.7
8.2
6*8
7*7
10*4
10*9
9*1
6*8
- 394 -
-------
RUN 7: TEMPERATURES AND FEED RATES
PAGE 4 OF 10
DAY.HOUR TEMPERATURE* DEC. C.
GASIFIER REGEN. RECYCLE
FEED RATE KG/MR
OIL STONE
6.123(9
6.1330
6*1430
6.1530
6.1630
6.1730
6.1830
6.1930
6.2030
6.2130
6.2230
6.2330
7.0030
7.0130
7.0230
7.0330
7.0430
7.0530
7.0630
7.0730
7.0830
7.0930
7.1030
7.1 130
7.1230
7.1330
7.1430
7.1530
7.1630
7.1730
7.1830
7.1930
7.2030
7.2130
7.2230
7.2330
8*0030
8.0130
8*0230
878.
888.
878.
881 .
880.
874.
890*
919.
923.
924.
926.
921 .
910.
918.
912.
903.
921 .
920.
914.
908*
899.
903-
903.
902.
902.
898.
899.
895.
890.
896.
898.
905.
902.
909.
907.
911.
919.
910.
909.
1078.
1069.
1072.
1070.
1070.
1062.
1070.
1060.
1072.
1070.
1078.
1065*
1072.
1074*
1072.
1072.
1072.
1074.
1078.
STONE
1070.
1069.
1070.
1067.
1065*
1065*
1067.
1070.
1070*
1069*
1069*
1062.
1070.
1066.
1069*
1069.
1069.
1071.
1069.
1069.
69.
68.
68*
68.
68.
66.
68.
62.
61 .
60.
60.
61.
61.
61 .
61*
60*
60*
60*
60.
CHANGE
60.
59.
62.
63*
63*
62.
64.
65.
65.
65.
62*
69.
61.
61*
60.
60.
60*
60*
61*
61.
192.5
191 .2
192.0
191.6
191 .2
192.5
190.8
192.5
192.0
192.0
191 .2
192.0
192.0
188.7
194.9
192.0
191 .6
191.6
191.6
192.5
192.9
192.0
193.3
183*8
193.3
192.0
192.9
192.5
190.0
193.3
192.9
191 .6
193*3
190.4
192.0
191.6
191 .2
191 .6
192*0
5.0
6.4
7.3
7.7
7.3
10.4
8.6
6.8
8*6
7.3
8*6
7.7
5.9
9. 1
9.1
9. 1
6.8
7.3
3.2
15.4
18* 1
13.6
11.8
12.7
13*6
13.2
1 1.8
14. 1
15.0
14.5
10.9
10.9
12.7
10.9
9.5
7.7
9.5
10.4
10.9
- 395 -
-------
RUN 7: TEMPERATURES AND FEED RATES
PAGE 5 OF 10
8.0330
8.0430
8.0530
8.0630
8.0730
8*0830
SHUT
9.0530
9.0630
9.0730
9.0830
9.0930
9. 1030
9.1 130
9.1230
9. 1330
9. 1430
9-1530
9. 1630
9.J730
9-1830
9.1930
9.2030
9 . 2 1 30
9.2230
9.2330
10.0030
1 0 * 0 1 30
10.0230
10.0330
10.0430
10.0530
10.0630
10.0730
10.0830
10.0930
908.
903.
902.
8R8.
883.
881.
DOWN AT
889.
882.
902.
895.
882.
882.
872.
869.
868.
880.
892.
926.
950.
955.
922.
922.
908.
922.
922.
930.
930.
919.
924.
924.
922.
933.
922.
918.
900.
1070.
1067.
1062.
1071 .
1069.
1062.
8.0830
1039.
1045.
1052.
1059.
1050.
1056.
STONE
1058.
1060.
1060.
1065*
1066.
1068.
1062.
1068*
1068.
1065*
1064.
1064.
1062*
1062*
1060*
1062.
1062*
1062*
1062*
1062.
1062.
1062.
1063.
61 •
61 •
60*
60.
60.
60*
FOR 21
70.
70.
70.
71.
70.
68.
CHANGE
67.
65.
60.
57.
53.
50.
40.
•50.
30*
30*
32.
35.
39.
40.
39.
39.
38.
34.
35.
35.
40.
23.
25.
HOURS
FEED RATE
OIL
191.6
191 .6
192.0
191 -2
191 .6
191*6
173.1
183.8
178.0
175.6
175.1
175.6
177.6
181.7
183.8
184.2
183.8
185.5
184.6
194.9
190.8
190.8
190.4
190.4
190.8
190.4
191.2
190*4
190.4
191.6
190.8
191.2
190.8
190*4
191.2
KG/HR
STONE
1 1 *8
11 .8
13*6
22.2
26.3
28.6
26*8
30*4
25.4
25.4
23«6
30.8
29.0
46.7
54.0
50.3
51 .3
39.5
14.1
20*4
19*5
21*8
22.7
20.9
21*3
18*6
20.0
23*1
21 «8
22.2
22.2
21*8
23.1
23.6
31 .3
- 396 -
-------
RUN 7: TEMPERATURES AND FEED RATES
PAGE 6 OF 1
DAY. HOUR
0. 1030
0. 1 130
0.1230
0. 1 330
0. I 430
0.1530
0.1630
0. 1730
0. 1830
0. 1930
0.2030
0.2130
0.2230
0.2330
• 0030
.0130
.0230
.0330
.0430
.0530
.0630
.0730
• 0830
.0930
. 030
• 130
• 230
• 330
• 430
• 530
• 630
• 730
• 830
• 930
• 2030
• 2130
.2230
.2330
12.0030
TEMPERATURE*
GASIFIER
905.
910.
892.
888.
882.
895.
889.
870.
902.
919.
91 1.
912.
912.
910.
910.
912.
918.
916.
918.
912.
912.
914.
914.
905.
904.
910.
906.
905.
910.
922.
912.
912.
911.
915.
915.
900.
895.
885.
874.
REGEN
1068.
1070.
1068.
1068.
1070.
1070.
1069.
1070.
1071 .
1068.
1067.
1070.
1069.
1073.
1065.
1062.
1067.
1068.
1066.
1075.
1064.
1067.
1068.
1078.
1066.
1065.
1071 .
1070.
1070.
1070.
1070.
1070.
1060.
1062.
1065*
1060.
1060.
1053.
STONE
1060.
DEG. C-
. RECYCLE
26.
26.
26.
28.
29.
30.
30.
30.
30*
30.
28.
28.
25.
26.
28.
28.
28.
28.
28.
28.
28.
28.
26.
26.
27.
27.
30.
30.
30*
30.
30.
30*
30.
30*
30.
30*
60.
71.
CHANGE
72.
FEED RATE KG/HR
OIL
191 .6
189.2
193.3
190.8
190.8
191 .2
190.8
191.2
190.8
190.8
191 .2
190.8
190.8
191.2
190.8
190.4
190.8
190.8
190.4
191 .2
190.4
190.8
190.8
190.8
190.4
190.8
189.6
190.8
190.4
190*4
190.0
190.4
190.4
193.7
189.2
189.2
188.7
187.9
183*0
STONE
50.3
49.0
49.9
51.7
51 .3
48.5
50.8
54.9
29.5
20.0
21 .3
20.4
22.7
22.2
19.5
19.5
19.5
21 .8
22.7
23.6
22.7
22.7
22.7
23-6
23-6
22.2
23.6
25.4
22.2
18.1
18.1
19.1
23.6
0.3
21 .8
21 .3
12.2
0.9
26.3
- 397 -
-------
RUN 7: TEMPERATURES AND FEED RATES
PAGE 7 OF 10
DAY.HOUR TEMPERATURE* DEC. C»
GASIFIER REGEN. RECYCLE
FEED RATE KG/HR
OIL STONE
12.0130
12.0230
12.0330
12.0430
12.0530
12.0630
12.0730
12.0830
12.0930
12. 1030
12. 1 130
12* 1230
12.1330
12.1430
12. 1530
12. 1630
12. 1730
12. 1830
12. 1930
12*2030
12.21 30
12.2230
12.2330
13.0030
13*0130
13.0230
13*0330
13.0430
13.0530
13.0630
13.0730
13.0830
13.0930
13.1030
13*1130
13*1230
13*1 330
13. 1430
13*1530
13.1630
892.
900.
895.
893.
894.
895.
897.
889.
886-
879.
889.
890.
888.
883*
880.
875.
870.
884.
880.
879.
874.
876.
885.
892.
902.
909.
920.
918.
919.
916.
908.
919.
910.
920.
915.
920.
920.
918.
920.
920.
1060.
1052.
1054.
1055.
1050*
1050.
1052.
1050.
1050.
1060.
1055.
1059.
1060.
1060.
1060.
1059.
1058.
1059.
1055.
1062.
1058.
1058.
1059.
1060*
1060*
1067*
1072.
1062.
1063.
1060.
1066.
1065.
1052.
1071.
1055.
1061.
1062*
1058.
1058.
1058*
65.
40.
35.
36*
32.
34.
34.
33.
32.
29.
29.
32.
29.
29.
28*
30.
30*
30*
30.
30*
32*
32*
31*
42.
36*
34*
36.
38.
38*
38*
38*
39.
38.
41.
39.
32.
32.
30.
29.
28.
1 76.8
176.0
175.6
176.0
175.6
176.0
175.6
174.3
173.5
173.9
173.5
173.5
173- 1
173.5
173.5
172.7
173. 1
173.1
1 73.5
172.7
177.2
171.0
180.9
173-9
173.1
173.5
174.3
173.9
173.9
173.9
175.6
175.6
173.5
171.0
175.6
173*1
173*9
173.1
173.9
172.3
30.4
32.7
34.9
39.9
40.8
37.2
37.6
43* 1
39*5
36*7
27.7
32.2
33.6
32.2
37.6
38. 1
44.9
46*3
42.6
35.8
36*7
45*4
41 .3
33*6
34*9
37.6
26*8
29.9
28.6
39*0
30.8
40.4
31.8
32.2
18*6
15*0
10.0
1 1.8
11 .8
13.6
- 398 -
-------
RUN 7: TEMPERATURES AND FEED RATES
PAGE 8 OF 10
DAY.HOUR TEMPERATURE* DEC. C.
GASIFIER REGEN. RECYCLE
FEED RATE KG/HR
OIL STONE
13*1730
13. 1830
13. 1930
13.2030
13.2130
13.2230
13.2330
14.0030
14.0130
14.0230
14.0330
1 4.0430
14.0530
14.0630
14.0730
14.0830
14.0930
14. 1030
14. 1 130
14. 1230
14.1330
14. 1430
14.1530
14. 1630
14.1730
14. 1830
14.1930
14.2030
14.2130
14.2230
14.2330
15*0030
15.0130
15.0230
15.0330
15.0430
15.0530
15.0630
15.0730
15.0830
923-
918.
923.
925.
930.
928.
929.
919.
920.
921.
929.
883.
879.
880.
882.
890.
889.
881 .
881.
881 .
880.
881-
882.
881 .
872.
875.
870.
880.
878.
875.
886.
882.
880.
880.
885.
882.
882.
888.
888.
880.
1051 •
1049.
1049.
1058.
1060*
1059.
1059.
1059.
1048.
1059.
1061 .
1050.
1059.
1060.
1063*
1063*
1069.
1063*
1060.
1058.
1055.
1050.
1065.
1048*
1048*
1041 •
1042.
1048.
1042.
1045.
1048*
1045.
1049.
1041 •
1040.
1039.
1036.
1037.
1039.
1038*
28.
28.
23.
23.
37.
24*
29.
31 *
30.
30.
30.
52.
60.
61 •
61.
65.
62.
63.
62.
62.
62.
62.
62.
62*
60.
60.
61 .
60.
61.
61 .
61 .
61 .
59.
60.
62.
62.
58.
60.
61 .
59.
169.8
175.6
173.9
174.3
1 74.7
174.7
174.3
176.0
173.9
174.3
174.3
174.7
173.9
175.6
175.1
174.3
175-6
1 74.3
175.1
175.1
174.7
174.7
175. 1
175.1
174.7
174.7
174.7
175.1
176.0
176.0
173.5
174.3
175.6
175.1
175.6
174.3
174.3
175.1
174.3
173.9
16.8
18.1
19.5
14. 1
14*1
16.3
13*6
12.2
14.1
14. 1
12.7
12.2
13.2
14.5
12.7
12.7
12.2
13.2
12.7
1 1 .8
12.7
12.7
12-2
12.7
15.4
20.0
15.0
12.7
14.5
15.0
10.9
1 1 .3
13-2
16.8
15.0
15.9
17.2
15.9
14.5
20.4
- 399 -
-------
RUN 7: TEMPERATURES AND FEED RATES
PAGE 9 OF 10
DAY.HOUR TEMPERATURE* DEC. C.
GASIFIER REGEN. RECYCLE
FEED RATE KG/HR
OIL STONE
15.0930
15. 1030
15.1 130
15. 1230
15. 1330
15. 1430
15.1530
15. 1630
15.1730
15. 1830
15. 1930
15.2030
1 5 . 2 1 30
15.2230
15.2330
16.0030
16.0130
16*0230
16.0330
16.0430
16.0530
16.0630
16.0730
16.0830
16*0930
16.1030
16. 1 130
16. 1230
16. 1330
16. 1430
16. 1530
16. 1630
16.1730
16. 1830
16.1930
16.2030
16.2130
16.2230
16*2330
17.0030
879.
876.
876.
878.
890.
885*
884.
882.
877.
885.
883.
875.
898.
890.
877.
880.
900.
911.
932.
935*
917.
910.
902.
904.
898.
898.
899.
896.
896*
899*
898.
895-
895.
899.
900.
896.
895*
908*
910.
910.
1038*
1038.
1048*
1056*
1058*
1060.
1064.
1064*
1060.
1059.
1064.
1065.
1060.
1060.
1060.
1060*
1080.
1076.
1075.
1078.
1078.
1070.
1072*
1070.
1064.
1063*
1065.
1062.
1061 •
1062.
1060.
1060.
1057.
1060.
1066.
1059.
1062*
1060.
1065.
1062.
61 .
62.
63.
63*
63*
60*
60.
60.
61.
61.
62.
63.
60.
60.
60.
60.
60.
48.
42.
40.
40.
40.
40.
40.
41.
42.
41.
41 .
41.
41 .
50*
48.
48.
45.
46*
48*
45.
45*
45.
45.
175.1
174.7
174.7
174.7
174.3
174.3
1 74.7
1 74.3
1 74.7
174.7
174.3
1 74.7
174.7
173.9
173.9
174.3
172.3
173.9
174.3
173.9
173.9
174.7
174.3
173.5
173.9
174.3
174.3
173.9
174.7
174.3
174.3
175.6
175.6
176.4
176.0
175.1
175.1
175.6
1755.6
175.6
17*7
17.2
19.1
18.6
15.4
18. 1
17.2
15.9
17.2
16*8
15.0
19.5
16.3
15.9
18.6
15*4
14.5
16*8
17.2
10.9
13.2
15.0
14. 1
13.2
17.2
16*3
15*4
15*4
15.4
12.2
12.2
16.3
17.2
13.6
12*2
15.0
16*8
12.2
14. 1
13.2
- 400 -
-------
RUN 7: TEMPERATURES AND FEED RATES
PAGE 10 OF 10
DAY.HOUR TEMPERATURE> DEG. C«
GASIFIER REGEN. RECYCLE
FEED RATE KG/HR
OIL STONE
17.0130
17.0230
17.0330
17.0430
17.0530
17.0630
17.0730
17.0830
17.0930
17. 1030
17.1 130
17.1230
17. 1 330
17. 1430
17. 1530
17. 1630
17. 1730
17.1830
17.1930
17.2030
17-2130
902.
905.
903.
962.
894.
898.
890.
889.
910.
899.
894.
897.
898.
900.
894.
897.
893.
900.
902.
900.
892-
1055.
1055.
1054.
1053.
1055.
1056*
1053.
1050.
1055.
1056.
1055.
1058.
1058.
1057.
1054.
1054.
1057.
1056.
1060*
1059.
1060.
48.
48.
50.
50.
50.
50.
50.
50.
50.
49.
49.
48*
45.
45-
40.
37.
35.
35.
35.
36*
34.
174.3
174.7
173*5
175.6
174.3
175. 1
174.7
174.7
174.7
175. 1
1 75.1
175.6
176.0
173.9
175.1
168. 1
166.1
166.9
166*1
166* 1
165.7
13.2
11.3
9.5
1 1 .8
13.2
12.2
15.0
17.2
13*6
8.2
12.7
13.6
14.5
10.4
19.5
25.4
25.9
26.8
16>8
13.6
16.8
- 401 -
-------
APPENDIX D - TABLE II
RUN 71 GAS FLOW RATES PAGE 1 OF 10
DAY. HOUR
• 1230
• 1330
• 1430
.1530
• 1630
• 1730
• 1830
• 1930
• 2030
• 2130
• 2230
• 2330
2.0030
2 • 0 1 30
2.0230
2.0330
2.0430
2.0530
2.0630
2.0730
2.0830
2.0930
2. 1030
2. 11 30
2. 1230
2.1330
2.1430
2. 1530
2-1630
2. 1730
2.1830
2. 1930
2.2030
2.2130
2.2230
2.2330
3.0030
3.0130
3.0230
3*0330
GAS
GASIFIER
AIR
437.
41 1 .
394.
403*
386.
403.
386.
385.
402.
407.
420.
421 .
41 1 .
404.
412.
412.
421 .
421 .
430.
421.
430.
417.
415.
420.
416.
419.
416.
421 •
421 •
419.
416.
416.
416.
416.
416.
41 1 •
428.
428.
419.
419.
FLUE GAS
183.
214.
214*
224.
154.
1 44.
168*
165.
138.
132.
127.
1 7.
1 7.
1 7.
1 7.
1 7.
1 7.
107.
1^7.
107.
97.
97.
97.
87.
87.
87.
81.
79.
77.
77.
97.
91 .
87.
107.
97.
97.
97.
97.
97.
96.
RATE
PILOT
PROPANE
3.7
3.7
0.
0.
0.
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3*7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.8
3.8
3.7
3.7
3.7
3.7
3*6
3.6
3.6
3.7
3.6
3.6
3*6
3.6
3.6
3.6
3.6
S M3/HR REGEN.
REGENERATOR VELOCITY
AIR
31 .4
30*6
33.2
32.9
27.4
32.0
31 .7
33.3
26.8
27.1
27.7
28.0
28.5
27.7
28.9
32.8
31 .3
31 .0
30.3
31.0
30.3
30.7
29.1
29.4
2^.5
29.7
29.7
29.5
29.2
32.6
26.5
29.7
33-5
33.8
37. 1
33.2
34.7
33-5
31 .4
31 *4
NITROGEN M/SEC
4-5
4.7
3*0
2.6
3.4
3*6
3.8
3.7
2.8
2.5
2.5
2.8
2.6
2.9
2.5
2.9
2.6
2.9
2*6
2.9
2.5
2.7
2.5
2*5
2*5
2*5
2.4
2*4
2.4
2*5
2.2
4.2
2.8
4.3
4.3
4.3
4.4
4.7
2.5
2.5
• 54
.59
.63
.61
• 39
.62
• 59
.68
.33
• 36
.39
.42
.43
• 40
• 44
.65
.55
.55
• 50
.55
• 51
• 53
• 46
• 47
.48
.49
• 48
.47
• 47
• 63
• 34
• 56
• 67
• 73
.88
• 70
.78
.74
• 54
• 54
- 402 -
-------
3-
3<
3
3
3
3
3.
3
DAY.HOUR
3.0430
3.0530
3.0630
3.0730
3.0830
3.0930
3.1030
1 130
1230
1330
1430
1530
1630
1730
1830
3.1930
3.2030
3*2130
3.2230
3.2330
4.0030
4.0130
4.0230
4.0330
4.0430
4.0530
4.0630
4.0730
4.0830
4.0930
4.1030
4.1130
4.1230
4.1330
4>1430
4.1530
4.1630
4.1730
4.1830
4.1930
RUN 7:
GAS
GASIFIER
AIR FLUE GAS
419.
410.
428.
438.
438.
435.
437.
437.
436.
437.
436*
436*
437.
436.
436.
437.
436.
454.
436.
436*
437.
419.
437.
428.
437.
437.
428.
428.
428.
428.
428.
428.
419.
419.
420.
420*
432.
423.
431 •
431 .
87.
97.
97.
96.
97.
97.
97.
97.
97.
87.
87.
77.
77.
77.
67.
67.
67.
47.
47.
47.
47.
67.
47.
47.
47.
47.
47.
47.
47.
47.
47.
47.
47.
57.
57.
58.
58.
67.
67.
67.
GAS FLOW RATES PAGE 2 OF 1 0
RATES M3/HR REGEN.
PILOT REGENERATOR VELOCITY
PROPANE
3*6
3*6
3*6
3.7
3.7
3*6
3*6
3.6
3.7
3.6
3.7
3.6
3.6
3*6
3.7
3.7
3-7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3-7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
AIR NITROGEN M/SEC
30.5
31*1
30*8
33.5
32.6
32.6
32.6
32.4
32.4
32.4
30*8
32.0
27.9
27.3
27.0
27. 1
27.2
28.6
35*6
36.8
37.1
37.0
37.5
38.6
38.0
37.4
34.1
34.3
34.4
33.1
36.0
35.2
34.7
33.7
33.7
33.2
33.3
32-8
32.1
35.6
4.4 .59
4*1 .60
4.0 .59
4.3 .73
4.0 .67
4.0 .67
4.1 .68
4-0 .67
4.0 .66
4.1 .67
4.3 .60
4.2 .65
4.2 .47
4*2 1*44
4*3 1*44
4.3
4.3
4.4
4.3
4-3
2.5
2.6
2.6
2.6
2.2
2.0
2.2
1.7
1 .7
1 .9
2.1
3.1
3. 1
3.1
.44
.45
.51
.83
.89
.82
.82
.85
.91
.84
.82
.68
.67
.68
.62
.75
.76
.73
.69
3.2 1.68
3.1 L66
3-0 L67
3.0 1*64
3.1 1-62
3.0 1.78
- 403 -
-------
DAY.HOUR
4.
4.
4.
4.
5.
5.
5.
5.
2030
2130
2230
2330
0030
0130
0230
0330
5.0430
5.
5.
5.
5.
5.
5.
5.
5-
5.
5.
0530
0630
0730
0830
0930
1030
1 130
1230
1330
1430
5.1530
5.1630
5 . 1 7 30
5.1830
5.1930
5.
5.
5.
5-
6.
6.
6.
6.
6.
6.
6>
6.
6.
6.
6.
2030
2130
2230
2330
0030
0130
0230
0330
0430
0530
0630
0730
0830
0930
1030
RUN It
GAS
GASIFIER
AIR FLUE GAS
6*1130
431 •
433.
432.
423.
425.
425.
468.
467.
468.
467.
477.
477.
468.
468*
462.
471 .
482.
487.
479.
470.
478.
478.
477.
478*
478.
476.
477.
468*
477.
477.
477.
468.
468.
476.
477.
476.
476.
474.
474.
474.
67.
57.
57.
57.
57.
57.
58.
58.
58.
48.
48*
48.
48.
48.
48.
48.
48*
48.
48.
48.
58*
48*
68*
69.
58.
58.
48*
48.
48.
48.
48.
48.
48*
48.
48.
47.
47.
47.
37.
37.
GAS FLOW
RATE
PILOT
PROPANE
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
4.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3*6
3*6
3.6
3*6
3.7
3«6
3.6
3.6
3.7
3.7
3.7
3*6
3.6
3.6
3.6
3-6
3«7
RATES
S M3/H
PAGE 3 OF 10
R REGEN.
REGENERATOR VELOCITY
AIR NI
38.4
37.8
37.6
37.5
37.5
37.3
36.9
35.9
35.9
35.6
35.2
36*0
36.8
38.1
38.0
38. PI
38.7
36.7
36.7
35.7
31.7
31 -4
31-9
31 .2
31*1
31.9
31 .9
32.0
31.9
30.2
28.6
26.1
26*4
23.1
23.5
23.6
S3. 6
23-9
27.3
27.1
TROGEN M/SEC
3« 1 1 «90
3.6 L90
3.7
3*6
2.9
2.6
2.7
2.9
2.9
2.8
2.9
2.7
2.3
2.4
2.2
2.4
2.4
2.5
2.2
2.2
2.2
1 .9
1 .9 1
2.0
2.0
1 .9
2.0
2.0
2.0
2.0
.9
.7
.7
.7
.7
.7
.6
.7
• 6
.9
.89
.88
.85
.84
.80
.79
.77
.75
.73
.76
.80
.86
.84
.85
.89
.79
.79
.74
.55
• 53
55
.52
.51
.54
.54
.55
• 54
.47
.40
.27
• 28
• 4
. 5
• 5
• 5
• 8
• 32
• 33
- 404 -
-------
DAY.HOUR
6.
6.
6.
6.
6.
6.
6.
6.
6.
1230
1330
1430
1530
1630
1730
1830
1930
2030
6,2130
6.2230
6-2330
7.0030
7.0130
7.0230
7.0330
7.0430
7.0530
7.0630
7.0730
7.0830
7.0930
7.1030
7.1130
7
7.
1230
1330
7.1430
7.1530
7.1630
1730
1830
1930
7.2030
7.2130
7.2230
7.2330
8.0030
8.0130
8.0230
7.
7.
7.
RUN 7:
GAS
GASIFIER
AIR
447.
448*
434.
434.
439.
430.
440.
474.
474.
472.
466.
464.
455.
455.
455.
447.
446.
445.
446.
446.
446.
447.
447.
456.
456.
456.
454.
454.
457.
456*
456.
456.
456.
446*
445.
470.
472.
448.
447.
FLUE GAS
97.
87.
91.
91.
91.
77.
57.
37.
37.
47.
47.
57.
47*
47.
47.
47.
47.
47.
47.
STONE
47.
47.
47.
47.
37.
37.
37.
47.
47.
47.
47.
47.
47.
47.
47.
47.
47.
47.
47.
47.
GAS FLO
RAT
PILOT
PROPANE
3-7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.6
3.6
3.7
3.7
3.7
3.7
3.7
3.7
3-7
3-7
CHANGE
3.7
3.9
3.7
3.7
3.7
3-7
3.7
3.7
3.7
3.7
3. 7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
PAGE 4 OF
E S M3/HR
REGENERATOR
AIR NITROGEN
REGEN.
VELOCITY
M/SEC
27.4
27. 0
27.0
27.7
27.3
27.7
30.7
26.8
27.7
25.8
31.4
30.6
31 . 1
30. 7
32.2
31.3
32.0
31 .3
31 .7
28.5
27.4
27.4
27.3
26*8
27.4
25.9
26.2
29.0
28.7
29. 1
30.4
30.3
30.8
30.3
30.6
30.0
29.3
29.6
29.6
.6
.9
.6
.6
.9
.6
.9
.9
.9
.9
.9
.9
2.7
2.6
2.7
2.5
2.7
P.5
2.2
2
2
2
2<
2
2.
5
7
7
5
2
5
2.5
2.5
2.5
1 .9
3.2
2.2
2.2
1*6
3.2
3.0
2.7
2.6
2.7
2.7
33
32
31
34
33
33
49
30
35
1 .26
1.53
1 .47
54
51
59
54
58
54
55
1 .41
1 .37
1 .36
.35
.31
.35
.29
.30
.43
.38
.46
.47
.48
.46
.52
.52
.47
.44
.46
.46
- 405 -
-------
RUN 7: GAS FLOW RATES
PAGE 5 OF
8.0330
8.0430
8.0530
8.0630
8-0730
8.0830
SHUT
9.0530
9.0630
9.0730
9.0830
9.0930
9.1030
9 . 1 1 30
9. 1230
9.1330
9.1430
9.1530
9.1630
9.1730
9.1830
9.1930
9.2030
9.2130
9.2230
9.2330
10.0030
10.0130
10.0230
10.0330
10.0430
10.0530
10.0630
10.0730
10.0830
10.0930
448.
447.
447.
446.
446*
454.
DOWN AT
421.
437.
439.
423.
410.
386.
437.
472.
472.
506.
488.
471 .
507.
490.
448.
451.
452.
452.
452-
460.
461 .
451 •
451.
460.
461*
460.
461 •
460.
451 .
GAS
IER
UE GAS
47.
47.
47.
47.
47.
47.
8.0830
127.
108.
108*
106.
96.
105.
STONE
105.
75.
48.
46.
46.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
RAT
PILOT
PROPANE
3.7
3.7
3.7
3.7
3.7
3.7
FOR 21
3.6
3.6
3.7
3. 7
3.7
3.7
CHANGE
3.7
3.7
3.7
3.7
3*6
3.5
3.5
3.5
3.6
3.5
3.5
3.5
3.4
3*4
3.4
3.4
3.4
3*4
3.4
3.4
3*4
3*4
3.4
E S M
REG
AIR
29. 1
29.1
28.6
28.6
28.6
28.0
HOURS
29.5
32.6
28.0
36.7
27.6
31 .1
30.8
28.8
28.7
28.5
28.7
28.0
28.3
28.5
29.4
29.2
29*4
29.3
29.1
29.6
29.4
29.4
29.5
29.6
29.4
29.7
29.3
29.9
29.6
2.9
2.6
2.3
2.4
2.4
2.4
2.7
2.1
2.6
2.6
2.7
2.9
3.2
3.4
3*4
3.1
3*0
3*0
3*0
3.1
3*1
3.0
3*0
3*2
3.0
2.9
3.1
3.1
3*0
.46
.59
.38
.79
.37
• 54
• 54
.42
.43
.44
.45
.43
.44
.47
.51
.49
.49
.49
.47
• 50
.49
.49
.49
• 51
.49
• 50
• 49
• 51
.50
- 406 -
-------
RUN 7: GAS FLOW RATES
PAGE 6 OF IP)
DAY.HOUR
GASIFIER
AIR FLUE (
E S M3/HR
REGENERATOR
• AIR NITROGEN
REGEN.
VELOCITY
M/SEC
0. 1030
0.1 130
0. 1230
0. 1330
0. 1430
0* 1530
0. 1630
0.1730
0.1830
0. 1930
0.2030
0.2130
0.2230
0.2330
.0030
.0130
.0230
.0330
• 0430
.0530
.0630
.0730
.0830
.0930
.1030
• 1 130
.1230
.1330
.1430
.1530
.1630
.1730
.1830
• 1930
.2030
.2130
1 .2230
1 .2330
12*0030
476*
471.
467.
458*
467.
466*
457.
459-
457.
466.
466*
466.
466.
466*
466*
466.
465.
465.
465*
466.
466.
467.
477.
475.
465.
475.
482.
473.
482*
482*
481 •
482.
481 .
428.
482.
481.
438.
421 .
421 .
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
59.
109.
69.
STONE
69*
3*4
3*4
3*4
3.4
3.4
3*4
3*4
3*4
3*4
3*4
3.4
3.4
3.4
3*4
3.4
3.4
3.5
3.5
3.5
3.5
3.5
3-5
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
-
3.4
3.5
3.5
3.5
CHANGE
3.5
29.1
28.6
29.2
28*4
28.2
27.8
27.6
28*0
28.2
28.2
28.4
28.3
28.7
28*4
28.4
28.3
28.4
28.5
28.9
28. 7
28*6
28.5
28.3
28.4
27.9
28*0
27.4
27.6
27.4
27.3
27.4
27.5
27.4
-
29*9
29.9
30.0
31 .9
32.8
3.1 1
3.2 1
3.3
3.2
3.3
2.9
3.7
3.6
3.4
3.5
3*6
3.9
3*8
4.1
4.5
4.6
4.8
4.5
5.1
4.9
5.4
4.8
5.3
5*0
6.3
4.2
7.0
7.4
7.3
7.2
7.6
7.8
3.9
-
3-0
3.1
2.8
2.9
2*8
• 48
.47
.50
.46
.45
.42
.45
• 46
.46
.46
.48
.49
.50
.50
• 51
.51
.3
.52
.56
.56
.56
.53
.55
1.55
1 .57
1 .48
1.59
.61
.60
.59
• 61
.62
• 43
-
-51
.51
.50
.58
1 .63
- 407 -
-------
RUN 7» GAS FLOW RATES
PAGE 7 OF 10
DAY.HOUR
GAS
GASIFIER
AIR FLUE GAS
RATES M3/HR REGEN.
PILOT REGENERATOR VELOCITY
PROPANE AIR NITROGEN M/SEC
12.0130
12.0230
12*0330
12.0430
12.0530
12*0630
12.0730
12.0830
12.0930
12. 1030
12. 1 130
12.1230
12.1330
12. 1430
12. 1530
12. 1630
12.1730
12. 1830
12.1930
12.2030
1 2 . 2 1 30
12.2230
12.2330
13*0030
1 3 • 0 I 30
13.0230
13.0330
13.0430
13.0530
13.0630
13.0730
13.0830
13.0930
13*1030
13* 1 130
13*1230
13* 1330
13*1430
1 3* 1530
13* 1630
438.
439.
440*
439.
439.
440*
439.
438.
430.
422.
421 .
420*
422.
423.
422.
431 .
439.
449.
448*
448.
448.
448*
448.
448*
465.
465*
474*
474*
474*
465*
465*
474*
466.
473*
449*
448*
430*
431 *
430*
430*
68.
69.
59.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7*
7.
7.
7.
7.
7.
7.
7.
7*
7.
7.
7.
7.
7.
7*
7.
7.
7*
3*5
3*5
3*5
3*5
3.5
3.5
3.5
3.5
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3*7
3*7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3*7
3.7
3.7
3.7
3.7
3.7
3*6
3*6
3.6
3*6
3*7
3.6
3*6
3*6
30.0
29.8
29.8
29.9
28.9
28.3
28*2
28.2
28.8
30*7
30.2
30*0
29*7
29.5
31 .7
34. 1
31 .1
29.5
25.3
28.2
28.3
28.0
27.3
27*1
27.7
27.1
28.9
28.9
28*0
29.2
27.4
28.0
29.7
27.7
29.5
27.7
28.9
29.2
29.0
28.9
2.8
2.8
2.8
2.0
3-3
2.5
2*4
2*4
2.3
2*5
2*2
2*7
2*2
2.4
2.4
2.7
2.5
2.9
2.6
2.7
2-6
2.5
2.7
2.9
2.9
1 .6
2.9
5.6
4.2
3.3
3.4
3. 1
4.0
4.5
6.1
5.4
5.0
5.3
4.5
4.3
.51
.49
.49
.46
.46
• 41
• 39
• 39
• 42
.53
• 49
.50
.47
.47
I .56
1 .69
• 54
.48
.27
• 42
• 42
.40
.38
.37
• 40
.32
.47
.58
.48
.49
• 41
• 43
• 53
.48
.62
• 52
.56
.58
.53
.52
- 408 -
-------
RUN 7: GAS FLOW RATES
PAGE 8 OF 10
DAY.HOUR
GAS
GASIFIER
AIR FLUE GAS
RATES M3/HR REGEN.
PILOT REGENERATOR VELOCITY
PROPANE AIR NITROGEN M/SEC
3.1730
3-1830
3. 1930
3.2030
3*2130
3.2230
13.2330
14.0030
14.0130
1 4.0230
14.0330
14.0430
14.0530
1 4.0630
14.0730
14.0830
1 4.0930
1 4. 1030
14. 1 130
1 4. 1230
14. 1330
1 4. 1 430
14. 1530
14. 1630
14. 1730
14. 1830
14. 1930
1 4.2030
1 4.2130
1 4.2230
14.2330
1 5.0030
15.0130
15-0230
1 5.0330
1 5.0430
1 5.0530
15.0630
15.0730
1 5.0830
435.
435.
436.
435.
435.
435.
435.
444.
444.
435.
435.
418.
418.
418.
426.
426.
426.
416.
41 7.
408.
408.
416.
408.
408.
408.
408.
407.
408*
416.
416.
416.
416.
416.
416.
416*
425.
425.
416.
416.
416.
7.
27.
28.
28.
27.
28.
27.
48.
48.
48*
48.
47.
77.
47.
47.
47.
47.
47.
47.
47.
47.
47.
47.
47.
47.
47.
47.
47.
47.
47.
47.
47.
47.
47.
47.
47.
47.
47.
47,
47.
3*6
3*6
3*6
3*6
3.6
3.6
3*6
3.5
3.5
3.5
3.5
3.7
3.7
3.7
3.7
3.7
3*6
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
3.7
28.6
28.5
28.2
28.4
28.4
28.4
28.9
27.4
26.8
27.1
27.1
30.1
25.9
28.6
28.0
28.0
28.0
28.5
28.2
28.2
27.9
28.2
28.2
28-0
28.2
28.2
28.0
28.3
28.2
28.2
28-0
28.9
29.8
30. 1
30.8
28.9
27.7
28-0
27.7
27.7
4.0
3.6
2.4
4.8
4.3
4.3
4.4
3.6
4.5
3.7
3*6
4.0
3.7
3.7
3.8
3.7
4.3
4*4
4.8
4.4
4.6
4.2
4.2
3.6
4.8
4.7
5.6
6.2
5.9
6.0
5.8
8.3
8.3
6.6
3.7
4.0
3.4
3.0
3.4
3.0
.48
.46
• 39
.52
.50
.49
.52
.42
.42
.41
.40
.54
.35
.47
.45
.45
.48
.50
.50
.48
.47
.46
.48
.43
.49
1 .48
1.51
.55
.53
• 54
.52
.67
.72
.65
.54
.47
• 39
1.39
1-39
1.3R
- 409 -
-------
DAY.HOUR
5.
5.
5.
5-
5.
5.
5.
5.
5.
5.
5.
.0930
. 1030
• 1 1 30
1230
1330
. 1430
. 1530
. 1630
.1730
1830
1930
5.2030
5.2130
5.2230
5.2330
16.0030
16.0130
16.0230
16.0330
16.0430
16.0530
16.0630
16.0730
1^.0830
16.0930
16.1030
16.1130
16.1230
1330
1430
1530
1630
1730
1830
1930
16.2030
16.2130
16.2230
16.2330
17.0030
16-
16.
16-
16.
16.
16.
16.
RUN 7:
GAS
GASIFIER
AIR
416.
424.
4)6.
424.
423.
423.
414.
406.
406.
406.
407.
406.
407.
398.
407.
407.
441 .
442.
442.
442.
476.
442.
442.
441 •
408.
407.
406.
398.
398.
398.
407.
387.
410.
41 1 •
409.
392.
392.
392.
392.
389.
FLUE GAS
57.
57.
57.
67.
67.
67.
67.
67.
57.
67.
67.
67.
67.
67.
67.
67.
47.
47.
47.
47.
47.
47.
47.
47.
47.
47.
58.
58.
47.
58.
47.
47.
47.
47.
47.
57.
57.
57.
57.
57.
GAS FLOW
RATE
PILOT
PROPANE
3.5
3.5
3.5
3.5
3.5
3.5
3.5
3.5
3.5
3.5
3.5
3.5
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.5
3.5
3.5
3.5
3.4
3.4
3.4
3.4
3.4
3.4
3*4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.5
3.5
3.5
RATES
S M
REG
AIR
27.6
27.6
29. 1
34.9
36. 1
36. 1
37.5
38.8
38.7
41 .4
43.6
38.4
37.2
37.0
37.2
34. 1
34.6
31 .3
30*4
30.0
30.3
30.9
30.9
30.8
30.7
30.5
30.4
30.4
30. 1
29.8
29.3
29.3
29.4
28.5
29.7
29.9
29.9
29.7
29.7
29.5
PAGE 9 OF 1 PI
M3/HR
NERATOR
NITROGEN
3.0
3.?.
3.5
5.2
6.0
6.6
6.9
9.2
5.8
6.?
6*1
6.8
3.2
5.0
5. 1
5.0
8.1
6.6
6.0
7.7
7.5
7.0
6.7
5.9
5.5
4.9
4.8
4.5
4.4
4.6
4.4
4. 1
3.7
4-2
3.8
3.9
4.2
4*2
4.4
5.3
RE GEN.
VELOCITY
M/SEC
.37
.37
.47
.82
.91
.94
2. 19
2.02
2. 16
2.26
2.06
.83
.90
.92
. 77
.97
.75
• 67
.73
.74
.74
• 73
.68
.65
• 61
.61
.59
• 57
.57
.53
.51
.50
• 48
.5?
.53
.55
.54
.55
.58
- 410 -
-------
DAY.HOUR
17.0130
17.0230
1 7.0330
1 7.0430
17.0530
17.0630
17.0730
17.0830
17.0930
17.1030
17.1130
17.1230
17.1330
17.1430
17.1530
17.1630
17.1730
17. 1830
17.1930
17.2030
17.2130
RUN 7:
GAS
GASIFIER
AIR FLUE GAS
384.
384.
385.
384.
385.
385.
384.
385.
372.
381.
380.
380.
380.
380.
379.
372.
371.
380.
372.
371.
371 .
57.
57.
57.
57.
57.
57.
57.
57.
57.
57.
57.
47.
57.
57.
7.
7.
7.
7.
7.
7.
7.
GAS FLOW RATES PAGE 10 OF 10
RATES M3/HR REGEN.
PILOT REGENERATOR VELOCITY
PROPANE
3.5
3.5
3.4
3.4
3.5
3.5
3.5
3.5
3*4
3.4
3.4
3.4
3*4
3.4
3.4
3.4
3-4
3.4
3.4
3.4
3.4
AIR NITROGEN M/SEC
29.4
29.4
29.8
29.8
28.4
28.3
34.3
28.2
28.0
28*1
28.0
27.7
29.0
30.8
30.6
30.7
30.4
30.4
30.1
29.9
29.3
3.2
4* 1
4.2
4.0
3.6
3.5
3.4
3.0
3.1
3.8
3.5
3.6
3.9
4.0
3.8
3.4
4.5
3.9
4.7
4.5
4. 1
.47
• 51
.52
.52
.44
.43
.69
.39
.40
• 43
.42
.41
.48
.56
.54
.53
.56
.54
.56
.54
.49
- 411 -
-------
DAY.HOUR
APPENDIX D - TABLE III
RUN 7: PRESSURES PAGE
GASIFIER P. KILOPASCALS GASIFIER
GAS DISTRIB. BED BED
SPACE D.P. D.P. SP. GR.
1 OF IP)
REGEN.
BED
D.P.
. 1230
• 1330
• 1430
• 1530
• 1630
. 1730
• 1830
• 1930
• 2030
• 21 30
•2230
.2330
2.0030
2.0130
2.0230
2.0330
2.0430
2.0530
2.0630
2.0730
2.0830
2.0930
2. 1030
2 . 1 1 30
2. 1230
2.1330
2. 1430
2.1530
2. 1630
2. 1730
2. 1830
2.1930
2.2030
2.2130
2.2230
2.2330
3.0030
3 . 0 1 30
3.0230
3.0330
3.9 4.'
4. 1 4.
4.0 4*!
3.9 4.!
3.6 3.1
3*6 3.
3.9 3-
3.7 3.
3-7 3.<
3.7 3.5
3.7 3..
3-7 3.'
4.1 3*'
4.0 3.;
4.1 3.
4.0 3*2
4.1 3.5
4.1 3.1
4.1 3.J
4.0 3.J
4.1 3*
4. 1 3*
3.9 3.
4.0 3.
4.0 3.f
3.9 3.
4.0 3*
4.0 3.
4.0 3.
3.9 3.
4.0 3*2
4. 1 3.
4.2 3-
4.1 3«S
4.2 3.J
4.1 3.2
4.2 3.-<
4.1 3»J
4*1 3*i
4.0 3*£
? 4.9
? 4.7
> 5.0
? 4.7
? 4.9
5 5.0
5 5.0
5 5.2
4 5.1
> 5.0
4 5.0
j 4.7
4 4.5
> 4.4
1 4.4
> 4.4
> 4.5
> 4.5
> 4.2
> 4.5
4.5
4.7
4.9
4.7
5 4.6
4.6
4.5
4*5
4.5
4.5
> 4.5
4.6
4.7
> 4. 7
> 5.0
> 5.0
\ 5.0
> 5.0
> 5.1
> 5.2
.05
.00 9
• 05
.05
.05
1 .05
1 .05
.05
.05
.05
.00
-10
.10
• 10
• 10
.00
.10
.00
.00
.05
.05
.05
• 00
1 .05
1 .00
.00
.05
.05
• 05
.05
.00
.05
.05
.10
.10
• 00
.00
.00
.00
.00
6.0
7.0
5.2
6.3
6.0
6.5
6-2
6.2
5.5
5.0
4.7
4.2
4.5
5.0
4. 1
4.2
4.2
4.5
4.2
5.0
5.0
5-2
5.5
5.4
5.2
6.2
5.5
5.5
5.5
5.5
5.5
5.5
5.5
5.5
5.5
5.5
7.5
7.3
7.5
7.5
- 412 -
-------
RUN 7: PRESSURES
PAGE 2 OF 10
DAY. HOUR
3.0430
3.0530
3.0630
3.0730
3*0830
3.0930
3* 1030
3. 11 30
3. 1230
3. 1330
3. 1430
3-1530
3.1630
3. 1730
3.1830
3-1930
3.2030
3.2130
3.2230
3.2330
4.0030
4.0130
4.0230
4.0330
4.0430
4.0530
4.0630
4.0730
4.0830
4-0930
4. 1030
4. 1 130
4.1230
4. 1330
4.1430
4. 1530
4. 1630
4.1730
4. 1830
4. 1930
GASIFI
GAS
SPACE
4.0
4. 1
4-2
4. 1
4.2
4.2
4.2
4.
4.
4.
4.
4.
4*
4.
4.0
4.0
4.0
4.0
3.9
4.0
4.0
4.1
4.0
4*0
4.0
4.
4.
4.
4.
4.
4*0
3.9
4.0
4.1
4.2
4.2
4.2
4.5
4.4
4*4
ER P. KILOPASCALS GASIFIER
DISTRIB.
D.P.
3.2
3.4
3.5
3.6
3.5
3.5
3.5
3.5
3.5
3.4
3.4
3.4
3.2
3.4
3-2
3.2
3.2
3.2
3.2
3. 1
3.0
3.2
3.1
3«
3.
3.
3.0
3.
3.
3.0
3.0
2.9
3*0
3.1
3.1
3. 1
3.1
3.2 $
3.2
3.1
BED BED
D.P. SP. GR.
5.2
5.2
5.2
5.2
5.5
5.4
5.4
5.4
5.6
5.7
5.7
5.7
5.8
5.8
6.0
6.1
6.2
6.1
6. 1
5.7
6.2
6*1
6.1
6.2
6.2
6.2
6.2
6*2
6*2
6.0
6*0
6.
6.
6.
6.
6*
6.
6 •
6.2
6*2
.05
.00
.00
.05
.05
.05
.00
.05
.00
.00
• 00
.00
• 00
.00
.00
*00
.00
.00
• 00
.00
.00
.05
.00
.05
.05
.05
.05
• 05
.05
.05
.05
.00
• 00
.00
.00
.00
.00
.00
.05
.05
REGEN
BED
D.P.
7.5
7.5
7.7
7.6
7.5
7.6
7.5
7.6
7.6
7.7
7.7
8.0
8.1
8. 1
8.0
8.0
8. 1
8.5
8.0
7.7
7.7
8.0
9.0
8.5
8.7
8.2
8.2
8.0
8.5
8.5
8.5
8.6
8.6
9.0
9.0
8-7
8.7
8.7
9.0
8.7
- 413 -
-------
RUN 7: PRESSURES
PAGE 3 OF 10
DAY. HOUR
4.2(930
4.2130
4.2230
4.2330
5.0030
5.0130
5.0230
5.0330
5.0430
5.0530
5.0630
5.0730
5.0830
5.0930
5.1030
5. 11 30
5. 1230
5. 1330
5.1430
5*1530
5. 1630
5. 1730
5.1830
5.1930
5.2030
5.2130
5.2230
5.2330
6.0030
6.0130
6.0230
6.0330
6.0430
6.0530
6.0630
6.0730
6.0830
6.0930
6. 1030
6.1 130
GASIFIER P. KILOPASCALS GASIFIER
GAS DISTRIB. BED BED
SPACE
4.2
4*4
4.4
4.1
4.2
4.3
4*6
4.6
4*6
4.7
4.7
4.7
4.7
4.7
4.7
4.7
4.7
4*9
4.7
4.6
4. 7
4.6
4.6
4.7
4.9
4.9
4.9
5.0
5.0
5.0
4.8
4.9
4.9
5.0
5.1
5.2
5.2
5.2
5.1
5. 1
D.P.
3.
3-
3.
3*
3.
3.0
3*4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.4
3.1
3.1
3.1
3*0
3*0
3*0
3*0
3.1
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3.2
3-5
3.4
3.5
3.5
3.4
D.P. SP. GR.
6.2
6.2
6*3
6.3
6.3
6.3
6.5
6.5
6.5
6.5
6*5
6*5
6.5
6.5
6.5
6.5
6.2
6*2
6*2
6*2
6 • 3
6.2
6*2
6.2
6*2
6*0
6*0
6.0
6.0
5*8
5.8
5.7
.00
.05
.05
.10
.10
.10
.10
• 05
.05
.05
.05
.05
.05
.05
.05
.05
.05
.05
.05
.05
.05
.05
.05
.05
• 05
.05
.05
.05
.05
.10
• 10
.10
5*8 1.10
5.8 1-10
5.8 1.10
5*5 1.05
5.5 1-10
5*6 1*10
5.7 1.10
5.7 1 • 10
REGEN
BED
D.P.
8.7
8.7
8.7
8.7
8.7
8.7
9.2
8.7
8.7
8.7
8.5
8.5
8.5
8.7
8.7
8.7
8.7
9.5
9.0
9.2
9.0
9.0
9.0
9.0
8.7
8.7
8.7
8.7
8.7
7.5
8.0
8.2
8.?
8.5
8.5
8.5
8.5
8.5
8.5
8.5
- 414 -
-------
RUN 7: PRESSURES
PAGE 4 OF 10
DAY. HOUR
6. 1230
6. 133(9
6. 1430
6. 1530
6. 1630
6. 1730
6. 1830
6. 1930
6.2030
6.2130
6.2230
6-2330
7.0030
7.0130
7.0230
7.0330
7.0430
7.0530
7.0630
7.0730
7.0B30
7.0930
7. 1030
7.1130
7. 1230
7. 1330
7. 1430
7. 1530
7. 1630
7. 1730
7.1830
7. 1930
7.2030
7.2130
7.2230
7.2330
8*0030
8*0130
8*0230
GASIFI
GAS
SPACE
5*0
5.
5.
5.
5.
5.
5.0
5.4
5.5
5.5
5.6
5.6
5.6
5*6
5.6
5.6
5*7
5.6
5.7
5.7
5.7
6.0
5.7
5.7
5.8
5*8
5*8
6.0
5.8
5.6
5*8
5-8
6*0
6*0
6.0
6*3
6*3
6. 1
6*1
ER P. KILOPASCALS GASIFIER
DISTRIB. BED BED
D.P. D.P. SP. GR.
3.7
3.7
3.5
3.6
3*6
3*6
3.6
3.7
3.5
3*6
3.7
3*7
3-6
3*5
3.6
3.6
3*6
3.6
3*6
STONE
3.5
3.6
3>6
3.5
3.5
3-5
3.6
3.7
3.7
3.7
3.7
3*6
3.7
3.7
3.6
3.7
3*7
3-7
3.7
3*6
5*7 .10
5.7 .10
5.6 .05
5.5 .10
5.5 .10
5.6 .10
5.6 .10
5-6 .10
5*6 .00
5.5 .00
5*5 .00
5.4 .00
5.2 .00
5*2 1.00
5*4 1.00
5.4 1.00
5.1 1.00
5.1
5.1
CHANGE
5«2
5.2
5.2
5-2
5.2
5-2
5-2
5.2
5.2
5.5
5.5
5.2
5.2
5.5
5*4
5.5
5.4
5*2
5. 1
5*1
.00
.00
.00
• 00
• 10
.10
.10
.00
.00
.00
.03
• 00
.00
.00
.00
.00
.05
.00
.00
.05
.05
• 00
RE GEN
BED
D.P.
8.5
8. 5
8.5
8.5
8.5
8.5
8.5
7.5
8.0
8.2
8*0
8.0
8*2
8.5
8*5
8.7
8.2
8.5
8.7
8.7
8.7
8.2
8.2
8.2
8.5
8.5
8.5
8.2
8.2
8.2
8.2
8.2
8.2
8.2
8.5
8.5
8.5
8*5
8.5
- 415 -
-------
RUN 7: PRESSURES
PAGE 5 OF IP)
8.0330
8.0430
8*0530
8.0630
8.0730
8.0830
SHUT
9.0530
9.0630
9.0730
9.0830
9.0930
9.1030
9 . 11 30
9. 1230
9.1330
9.1430
9.1530
9. 1630
9.1730
9.1830
9.1930
9.2030
9.2130
9.2230
9.2330
10.0030
10.0130
10.0230
10.0330
10.0430
10.0530
10.0630
10.0730
10.0830
10.0930
6.3
6.3
6.3
6.3
6*4
6.5
DOWN AT
3.7
3*8
3.7
3.6
3-5
3.6
3.6
3.6
3.6
3.7
3.9
3.9
4.0
4.0
3.7
3.7
3.7
3.7
3.7
3-9
3.9
3.9
3.9
3.9
3.9
3.9
3*8
3.9
3.9
R P. KILOPASCALS GASIFIER
DISTRI
D.P.
3-7
3.7
3.7
3.7
3-6
3.7
8.0830
4.6
4.6
4.5
4.2
3-9
4. 1
STONE
4-3
3.9
3.6
3.7
3»9
3*4
3-9
3.5
3.0
3*0
2.9
2.9
3*0
3*0
3*0
3*0
3*0
2.9
2.9
3*0
3*0
3.0
3.0
B. BED BED
D.P. SP. GR.
5*2 .00
5.2 .00
5*0 .00
5*0 .00
5*1 .00
5.2 .00
FOR 21 HOURS
4.2
4.3
4.S
4*5
4.6
4.7
CHANGE
4.7
4.9
5.2
5*2
5.2
5.2
5-0
5.0
4.7
5.0
4.9
5.0
4.9
4.7
4.7
4.7
4.7
4.7
4.7
5.0
4.7
4.6
4.7
.00
.00
.00
• 00
.00
.00
.00
.00
.00
• 00
.00
.00
.00
.00
.00
.00
.00
.00
• 00
.00
.00
.00
.00
.00
.00
.00
• 00
.00
.00
7.5
7.5
7.7
7.7
7.5
7.2
7.5
7.5
7.5
7.7
8.0
7.5
7.5
7.5
7.2
7.2
7.3
3
.2
7.2
7.2
7.3
7.3
7.2
7.2
7.2
7.2
7.2
7.2
7,
7
- 416 -
-------
RUN 7: PRESSURES
PAGE 6 OF 10
DAY. HOUR
0. 1030
0.1 130
0. 1230
0.1330
0. 1430
0. 1530
0.1630
0.1730
0. 1830
0.1930
0.2030
0.2130
0.2230
0.2330
.0030
• 0130
.0230
• 0330
.0430
• 0530
.0630
.0730
.0830
.0930
.1030
.1 130
. 1230
• 1330
• 1430
• 1 530
• 1630
.1730
.1830
• 1930
.2030
.2130
.2230
• 2330
12.0030
GASIFI
GAS
SPACE.
4.0
4.0
3.9
3.9
3.9
3.9
3.9
3.9
3.9
4.0
4.0
4.0
4.0
4.0
4.0
4*0
4.0
4.0
4.2
4.1
4.1
4.1
4.1
4.0
4.0
4.0
4.
4*
4.
4.
4.
4*
4.
4.2
4.2
4.2
4*1
4.0
4*0
ER P. KI
DISTRI
D.P.
2.9
2.2
2.2
2.2
2.2
2.0
2.0
2.1
2.2
2.2
2.2
2.2
2.2
2.2
3.2
3.2
3.2
3.2
3.2
3.4
3.4
3.4
3.2
3.2
3.2
3.2
3.4
3*4
3.4
3.5
3.5
3*4
3.4
3.4
3*4
3.7
3.7
3.9
STONE
3-4
LOPASCALS GASIFI ER
B. BED BED
D.P. SP. GR.
5*0 1.00
5.0 0.95
5.2 0.95
5.4 1.00
5*5 1.00
5.5
5.5
5*6
5.5
5.5
5.5
5.5
5.4
5.4
5.5
5.5
5.5
5.5
5.5
5.5
5-6
5.5
5.5
5.6
5.6
5.6
5.7
6*0
5.8
5.7
5.7
5.7
5-7
5.7
5.7
5.7
5*0
.00
• 00
.00
• 00
.00
• 00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
.00
• 00
• 00
.00
.00
.00
.00
.00
.00
4.5 0.95
CHANGE
4.7 1 .00
REGEN
BED
D.P.
7.5
8.0
8.2
8.2
8.5
8-5
8.5
8.5
8.2
8.2
8.2
8.2
8. 1
8.2
8.2
8.0
8*0
7.7
8.0
8.0
8.1
8.2
8.2
8.0
8.7
9.0
8.5
8.5
8.5
8.5
8.7
8.7
9.0
8.7
8.7
8.7
7.0
7.0
7.0
- 417 -
-------
RUN 7: PRESSURES
PAGE 7 OF 10
GASIFIER P. KILOPASCALS GASIFIER REGEN.
DAY.HOUR GAS DISTRIB. BED BED BED
SPACE D.P. D.P. SP» GR. D.P.
12.0130
12.0230
12*0330
12.0430
12.0530
12*0630
12.0730
12.0830
12.0930
12. 1030
12. 1 130
12-1230
12.1330
12.1430
12.1530
12. 1630
12.1730
12. 1830
12.1930
12.2030
12.2130
12.2230
12.2330
13.0030
13.0130
13.0230
13.0330
13.0430
13.0530
13*0630
13*0730
13*0830
13.0930
13*1030
13* H30
13*1230
13*1330
13. 1430
13.1530
13*1630
3.7
3.7
3*7
3.7
3.7
3.7
3*9
3.7
3.7
3-6
3.7
3.7
3.7
3.7
3*7
3.7
3.9
3.9
3*9
3.9
3.9
3.7
3.9
4*0
4.1
4*2
4.
4»
4*
4*
4*
4.2
4*2
4*2
4*0
4*0
3*9
3*7
3*9
3*9
3*0
3*0
3*0
2*9
3*0
3*0
3*0
2*9
2*9
2*7
2.7
2*7
2*7
2*7
2*7
2*9
2*9
3*0
3.1
3*0
3.0
3.0
3.0
3*0
3*2
3*4
3*2
3*4
3*2
3.2
3*4
3*4
3*4
3*2
3*0
3.0
2.7
2.7
2.9
2.9
4.9
4*5
4*4
4*4
4.4
4*4
4*2
4*4
4*6
4*7
5.0
5. 1
5.2
5.5
5*6
5.6
5.8
5*8
6.0
6* 1
6.0
5.8
5.8
5-8
5*7
5.6
5.5
5*6
5*6
5*6
5*6
5*6
5*6
5.5
5.5
5*2
5.2
5.2
5.2
5.2
0.95
0*95
0*95
0*95
0*95
0*95
0.95
0*95
0.95
0.95
0.95
0.95
.00
.00
.00
.00
.00
0*95
0*95
0*95
0.90
0.90
0.90
0.95
0.90
0*90
0.95
1.00
1 .00
1 .00
1.00
0.90
0*90
0*90
0*90
0*95
0*95
0*95
0*95
0*95
7.0
6*7
6.7
6.5
6*5
6*7
6.7
6.7
7.0
7.2
7.5
7.5
7.0
7.0
7.0
7.2
8.5
8*7
8*5
8.2
8.2
8.2
8.2
8.2
8*2
8-2
8.2
7.2
7.5
7.5
7.5
7.5
8.0
8.5
7.7
7*5
7.0
7.0
7.0
7.0
- 418 -
-------
RUN 7: PRESSURES
PAGE 8 OF 10
GASIFIER P. KILOPASCALS GASIFIER REGEN,
DAY.HOUR GAS DISTRIB. BED BED BED
SPACE D.P. D.P. SP. GR. D.P.
13.1730
13. 1830
13. 1930
13.2030
13.2130
13.2230
13.2330
14.0030
14.0130
14.0230
14.0330
14.0430
14.0530
14.0630
14.0730
14.0830
14.0930
14.1030
14. 1130
14.1230
14. 1330
1 4. 1430
14. 1 530
14. 1630
14.1730
14* 1830
14. 1930
14.2030
14.2130
14.2230
14.2330
1 5.0030
15.0130
15.0230
15.0330
1 5.0430
15.0530
1 5.0630
15.0730
15.0B30
3.9
4*0
4*0
4.0
4.1
4.2
4.2
4.1
4.1
4.2
4.2
4.6
4*5
4.6
4.6
4.6
4.6
4.6
4.6
4.6
4.7
4.7
4.7
4.7
4.7
4.6
4.7
4.9
4.7
4.7
4.7
4.7
4.7
4.7
4.7
4.7
4.7
4.7
4.7
4.7
2.9
2.9
2.9
2.9
2.9
2.9
2.9
3*0
3.0
3.0
3-0
3>6
3.7
3*6
3.4
3.4
3.4
3.5
3-5
3.5
3.5
3.5
3.5
3.5
3.5
3.4
3.4
3.5
3.5
3.4
3.5
3.5
3.6
3.5
3.5
3.4
3-4
3.4
3.4
3.2
5-4
5.4
5.2
5.2
5.2
5.1
5.2
5.1
5.5
5.5
5.5
5.5
5-4
5.4
5.4
5.4
5.4
5.2
5.4
5.2
5.2
5.2
5.2
5.2
5.4
5.5
5.4
5.2
5.2
5.2
5.2
5.2
5.2
5.2
5.2
5.2
5.2
5.2
5.2
5.2
0.95
0.95
0.95
0.95
0.95
1.00
0.95
.00
.05
.00
.00
.00
.05
.00
.05
.00
0.95
1 .00
0.95
1 .00
0.95
0.95
0.95
1 .00
0.95
.00
.00
.00
.00
.00
.00
.00
.00
.00
• 00
.00
0.95
1 .00
1 .00
1 .00
7.2
7.5
7.5
7.5
7.2
7.2
7.2
7.2
7.7
7.7
7.7
8.0
8.0
8.0
8.0
8.0
8.0
8.0
8.0
8.0
8*0
8*0
7.7
7*5
7.0
7.2
7.5
7.2
7.0
7.0
7.0
7.2
7.0
7.0
7.0
7.0
7.0
7.2
7.2
7.5
- 419 -
-------
RUN 7: PRESSURES
PAGE 9 OF 10
GASIFIER P. KILOPASCALS
DAY. HOUR
15*0930
15.1030
15*1 130
15. 1230
15. 1330
15.1430
1 5. 1 530
15.1630
15.1730
1 5*1830
15.1930
15.2030
15*2130
15.2230
15.2330
16.0030
16.0130
16.0230
16.0330
16.0430
16.0530
16*0630
16.0730
16.0830
16.0930
16. 1030
16. 1 130
16. 1230
16.1330
16. 1430
16. 1530
16. 1630
16. 1730
16. 1830
16. 1930
16*2030
16.2130
16.2230
16-2330
17.0030
GAS
SPACE
4.7
4.7
4.7
4.7
4.8
4.8
4*8
4.7
4.7
4.7
4.8
5.0
4*9
5*1
5.0
5*0
5.0
4.9
5.1
5. 1
4.7
4.7
4*6
4.7
4.7
4.7
4.7
4*7
4.8
4.8
5.0
4.9
5.
5*
5-
5.
5.
5.
5.2
5.1
DISTRIB.
D.P.
3-2
3.4
3.4
3.2
3.2
3*2
3.2
3.1
3*1
3.2
3. 1
3.2
3.2
3.2
3*2
3.2
3*2
2.9
3.1
3.1
2.7
2.7
2*6
2.5
2*6
2.6
2.5
2.5
2.5
2.5
2.6
2.4
2.4
2*5
2-5
2*4
2.4
2.4
2.4
2*4
BED
D.P.
5.5
5.5
5.5
5.5
5.5
5.4
5.4
5.4
5.4
5.4
5.2
5.2
5.2
5.0
5*1
5.2
5.2
5.2
5.2
5.2
5.2
5.2
5.2
5.4
5.4
5*4
5.5
5.5
5.5
5.6
5.6
5*6
5.6
5*6
5*6
5.6
5.6
5-6
5*4
5*5
GASIFIER
BED
SP. GR.
1 .00
0.95
0.95
1 .00
0.95
0.95
0.95
0.95
0.95
0.95
0.95
0.95
0.95
0.95
0.95
0.95
0.95
0.95
0.95
0.95
0.95
0.95
0.95
1 .00
0.95
0.95
1 .00
1 .00
0.95
0.95
1 .00
1 .00
0.95
0.95
1 .00
0.95
0.95
0.95
0.95
0.95
RE GEN
BED
D.P.
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.5
7.3
7.5
7.5
7.5
7.0
7.0
7.0
7.0
8.0
8.5
8.5
8.7
8.0
8.2
8.2
8.2
8.2
8.2
8.2
7.7
8.2
8.5
8.2
8.2
8.2
8.2
8.2
8.2
8.2
8.2
8.2
8.2
- 420 -
-------
RUN 7: PRESSURES
PAGE 10 OF 10
DAY. HOUR
7.0130
7.0230
7.0330
7.0430
7.0530
7.0630
7.0730
7.0830
7.0930
7. 1030
7. 11 30
7. 1230
7.1330
7.1430
7.1530
7.1630
7.1730
7.1830
7.1930
7.2030
7.2130
GASIFIER P* KILOPASCALS GASIFIER
GAS DISTRIB. BED BED
SPACE D-P. D.P. SP. GR.
5.5 2.5 5.5 0.95
5.5
5.6
5.6
5.7
5.8
5.7
5.8
5.9
5.6
5.7
5.8
5.8
6.0
6.0
5.9
6.0
6.3
6.4
6*6
6.7
2.5
2.5
2.5
2.5
2.5
2.5
2.5
2.5
2.4
2.4
2.4
2.2
2.2
2.2
2.1
2.1
2.2
2.1
2.2
2.1
5.5 0.95
5*4 1.00
5.4 1.00
5.4 0.95
5.2 0.95
5*2 1.00
5.4 0.95
5.4
5.4
5.4
5.4
5.4
5.4
5.4
5.5
5.5 {
5.4
5.4
5.4
5-2
.00
.05
.00
.00
.00
.00
.00
.00
3.95
.00
.00
.00
• 00
REGEN
BED
D.P.
8.5
8.7
8.7
8.7
8.2
8.2
8.2
8.2
8.2
8.2
5.0
8.2
8*2
8.2
8.5
8.2
8.2
8.2
8.0
8.2
8.5
- 421 -
-------
RUN 7:
APPENDIX
DESULPHURISATION
D: TABLE IV.
PERFORMANCE PAGE 1 OF 10
DAY. HOUR
. 1230
• 1330
• 1430
• 1530
• 1630
• 1730
• 1830
• 1930
.2030
• 2130
.2230
1 .2330
2.0030
2.0130
2.0230
2.0330
2.0430
2.0530
2.0630
2.0730
2.P830
2.0930
2. 15530
2. 1 130
2. 1230
2.1330
2. 1430
2. 1530
2. 1630
2. 1730
2. 1830
2.1930
2.2030
2.2130
2.2230
2.2330
3.0030
3*0130
3.0230
3.0330
SULPHUR GAS
REMOVAL VEL.
TL M/S
22.2
20.2
57.6
31 .2
51 .2
47.6
47. 1
49.9
51.2
51 .4
53.0
51 .5
48.2
53.6
59.0
58.0
61 .4
62.4
65.8
66.8
68 * 3
69.9
73.3
73.6
74.8
77.5
76.5
73.4
69.4
66.9
66.9
65.5
66.2
68.6
70.7
72.7
73.1
70.2
72.7
74.0
• 61
.63
.59
.63
• 37
• 39
• 43
• 41
• 37
• 37
• 38
.36
• 34
.30
• 33
.33
.35
.32
.34
• 32
• 30
.28
.26
• 24
.22
.24
.22
.23
.22
.22
.25
.24
.24
.29
.25
.23
.30
.27
.27
.26
G-BCD
DEPTH
CENTIM
47.
48.
48.
45.
47.
48.
48.
50.
49.
48.
50.
43.
41 •
40.
40.
44.
41.
45.
43.
43.
43.
45.
49.
45.
46.
46.
43.
43.
43.
43.
45.
44.
45.
43.
46.
50.
50.
50.
52.
52.
AIR/
FUEL
* ST.
24.6
23.4
22.5
23.4
21.1
22.0
20.9
20.8
2] .6
21.7
22.6
22.5
22.2
21 .7
22.2
22.3
22.7
22.6
23-2
22.6
23.2
22.4
22.3
22.7
22.4
22.5
22.2
22.5
22.4
22-1
22.6
22.3
22.3
22.3
22.2
22.0
22.8
23.3
22.2
22.2
CAO/S
RATIO
MOL.
0.
0.
0.
0* 16
1 .08
1*18
0.69
0.79
0.79
0.75
0.72
0.75
0.95
1 .04
0.92
• 12
• 24
• 34
• 38
.37
• 34
• 24
• 44
• 35
• 51
• 34
0.78
0.95
1 .04
1 .00
0.86
0.95
0.98
• 04
• 01
.04
.07
.15
.00
.07
* CAS
TO CAO
25.2
4.7
15.2
25. 1
33.8
39.9
39.9
43.6
51 .3
43.9
69.5
54.5
69.8
58.4
59.9
49.5
51 .4
65.9
77.8
48.2
45.5
63.4
65.4
66.8
75.2
74. 1
69.5
64.5
79.2
69.4
62.5
69.6
59.3
67.2
63.0
70.5
66.5
89.3
64.0
68.6
RE GEN.
S OUT X
OF FED
24.7
3.2
14. 5
24.6
28.8
40.6
38.8
46. 4
44* Pi
39. R
63. 1
47.8
64.7
52.4
54.2
52.7
53.5
66.4
72. 1
49.8
46.4
61 .7
60.3
66.6
69.9
73.3
68.5
63.9
79.2
73.7
56.5
7PI.6
64.2
66.9
72.0
74.3
72.5
83.9
65.3
69.9
- 422 -
-------
RUN 7:
APPENDIX Dt TABLE IV.
DESULPHURISATION PERFORMANCE PAGE
2 OF 10
DAY. HOUR
3.0430
3.0530
3.0630
3.0730
3.0830
3*0930
3.1030
3. 1 130
3. 1230
3.1330
3. 1430
3.1530
3. 1630
3.1730
3. 1830
3.1930
3.2030
3.2130
3.2230
3.2330
4.0030
4.0130
4.0230
4.0330
4.0430
4.0530
4.0630
4.0730
4.0830
4.0930
4. 1030
4.1 130
4. 1230
4.1330
4.1430
4.1530
4- 1630
4.1730
4.1830
4.1930
SULPHUR GAS
REMOVAL VEL.
% M/S
75.3
75.7
76.3
75.5
74. 1
74. 1
75.5
75.3
75.8
77.4
78.8
78.6
80.0
79.4
80.5
81.1
81 .4
81 .8
81 .8
82.2
82.4
81 .6
80* 1
79.5
77.9
75.5
78. P
80.6
80.2
79. 1
78.7
77.3
75.6
75.8
76-5
76.6
77.7
76.3
76.9
78.2
.22
.25
.29
.29
.30
• 30
.31
.31
.29
.28
.27
.23
.25
.22
.23
.23
.20
.24
.20
• 19
. 18
. 18
.18
. 14
.19
.17
. 1
. 5
. 5
• 4
. 5
. 5
. 1
.22
. 5
. 5
.30
. 16
.21
.22
G-BED
DEPTH
CENTIM
50.
53.
53.
50.
53.
52.
54.
52.
57.
58.
58.
58.
59.
59.
60.
62.
63.
62.
62.
58.
63.
59.
62.
60.
60.
60.
60.
60.
60.
58.
58-
62.
62.
62.
62.
62.
62.
62.
60.
60.
AIR/
FUEL
* ST.
22.3
21 .9
22.8
23.3
23.4
23.3
23.3
23.3
23.3
23.4
23.1
23.5
23.4
23-2
23.2
23.3
23.2
24.2
23.2
23. 1
22.6
21 .3
22.0
21 .3
21 .9
21 .8
21 .3
21.4
21 .3
21.4
21 .3
21 .4
21.2
21.3
21.3
21 .3
22.0
21.5
22*0
22.0
CAO/S
RATIO
MOL.
1 .07
0.98
1.53
.69
.86
.73
.60
.76
2.31
2-25
2.07
2.24
2.29
2.57
1 .95
2.21
2.05
2.06
1.17
0.84
0.76
0.84
0.90
0.76
0.83
0.77
0.67
0.77
0.95
0.77
0.61
0.77
0.78
0.78
0.84
0.75
0.69
0.90
1 .00
0.90
% CAS
TO CAO
75.4
72.9
66.7
66.2
67.6
64.9
66.8
66.0
71 .2
68.3
82.7
75.3
78.1
77.7
86.3
79.3
74.5
65. 1
75.8
77.6
77.2
71.5
83.4
98-3
89.0
72.9
69. 7
75.2
75.4
82.5
75.0
96.0
79.3
80.7
78.4
7R.9
77.8
93.5
68.6
70. 4
REGEN.
S OUT %
OF FED
73.7
74.0
68.3
73.9
75.7
73.3
73.9
67.6
77.9
72.1
80.3
85. 1
75.3
73.9
80.3
70.5
6R.3
61 .4
90.9
87. 1
86.4
77.2
85.9
89.7
82-?
70.0
69.2
73*2
75.2
76.3
75.4
77.5
73.0
75.3
7J .4
77.8
Rl .3
74.9
69. 8
77. 1
- 423 -
-------
RUN 7:
APPENDIX D: TAiLE IV.
DESULPHURISATION PERFORMANCE PAGE 3 OF lO
DAY. HOUR
4.203(5
4.2130
4.2230
4.2330
5.0030
5.0130
5.0230
5.0330
5.0430
5.0530
5.0630
5.0730
5.0R30
5.0930
5. 1030
5. ! 130
5. 1230
5.1330
5. 1430
5. 1 530
5. 1630
5. 1730
5. IB 30
5.1930
5.2030
5.2130
5.2230
5.2330
6.0030
6.0130
6.0230
6.0330
6.0430
6.0530
6.0630
6.0730
6.0830
6.0930
6.1030
6.1130
SULPHUR
REMOVAL
%
79.2
80.9
Rl .6
81.7
84.5
81 .9
79.6
79.5
79.8
80.9
81 .0
80.3
79.6
79.6
79.6
79. A
79.3
79.3
78.9
79.0
78.8
79,1
79.4
79.0
78.3
78.3
78.3
74.5
74.9
74.2
73.5
74. 1
74. 1
74.4
74.8
73.7
73.7
74.4
74.8
75.8
GAS
VEL.
M/S
1.20
1. 19
1 . 18
1.16
1. 15
1*14
1 • 18
1.19
1 • 19
1 • 18
1 • 19
1 .21
1 .19
1.19
1 . 16
1 . 18
1.21
1 .22
1.20
1*16
1 • 18
1.17
1.17
1.17
1.20
1 .20
1.21
1 • 18
1 .20
1 .20
1 .20
1 . 18
1 • 18
1 .20
1 .20
1 .24
1 .30
1 .26
1 .38
1 .23
G-BED
DEPTH
CENTIM
63.
60.
61.
58.
58.
58.
60.
62.
62.
62.
62.
62.
62.
62.
62.
62.
60.
60.
60.
60.
61.
60.
60.
60*
60.
58.
58.
58.
58.
54.
54.
53.
54.
54.
54.
53-
50.
51 .
53.
53.
AIR/
FUEL
% ST.
21 .9
22.0
21 .8
21 -5
21 .5
21.5
23.5
23.6
23.6
23.4
23.4
23.4
22.9
22.9
22.6
23.0
23.6
23.8
23.4
23.0
23*4
23.4
23.3
23.4
23.5
23-3
23.4
23.0
23.4
23.3
23*2
22.7
22.7
23.0
23.1
23.2
23.2
23.0
23.2
23.0
CAO/S
RATIO
MOL.
0.78
0.81
0.90
0.84
0.84
0.84
0.99
1 .00
0.96
1 .02
0.97
0.81
0.99
0.81
0.69
0.81
0.78
0.84
0.84
0.88
0.91
0.79
0.57
0.51
0.45
0.36
0.45
0.45
0.45
0.48
0.54
0.48
0.51
0.54
0.45
0.51
0.69
0.72
0.60
0.45
% CAS
TO CAO
63.0
81 .6
81.3
104. 4
83. 1
73.3
95.6
69.5
64.0
75.2
71 .8
76.4
80.9
77.5
75.7
70.2
74.8
75.4
77. 1
72.6
85.2
1 10.8
82.4
98.3
81.0
90.5
1 10*5
66* 1
102.3
83. 1
77.0
80.7
83-9
84.3
79.0
83.9
86.2
103.4
90.6
89.7
RE REN.
S OUT 7,
OF FED
78.9
80.7
75.4
82.8
78.4
72.0
84.9
79.2
75.8
78.9
78.2
83.7
79. 4
79.6
82.9
80. 1
84. 3
80.6
80.6
81 . 5
78. 5
80.8
76.0
86. 2
72.6
80.7
101 .6
68. *
98. 1
67.5
71.7
67.5
68.5
61.6
59.3
64. 1
68.2
72.1
79.0
79.4
- 424 -
-------
RUN 7:
APPENDIX Dl TABLE IV.
DESULPHURISATION PERFORMANCE PAGE
4 OF 1O
DAY. HOUR
6. 1230
6.1330
6*1430
6.1 530
6.1630
6.1730
6« 1830
6. 1930
6.2030
6.2130
6.2230
6.2330
7.0030
7.0130
7.0230
7.0330
7.0430
7.0530
7.0630
7.073PI
7.0830
7.0930
7.1030
7.1 130
7.1230
7.1330
7. 1430
7.1530
7. 1630
7.1730
7.1830
7.1930
7.2030
7.2130
7.2230
7.2330
8*0030
8.0130
8.0230
SULPHUR GAS
REMOVAL VEL.
% M/S
73. 1
71 .4
71 .0
71 .0
69.3
68.3
58.6
68-3
69.9
69.2
68.5
67.6
66.3
67.2
66.8
66.7
66.4
64>4
63.9
63. 1
63.9
65.4
66.6
66.5
66.6
66.8
66.8
66.3
66.2
66.3
66.6
67.6
68*4
69.8
68.5
68.4
68.7
67.7
67.2
.32
.30
.26
.27
.28
.21
.19
• 33
• 31
• 31
• 32
.34
.28
• 31
.28
.28
.30
.28
.26
.23
.22
• 24
.23
.25
.25
• 17
.32
.32
.33
.32
.36
.32
• 32
• 28
.26
.34
.35
.29
.29
G-BED
DEPTH
AIR/
FUEL
CAO/S REGEN.
RATIO % CAS S OUT 1
CENTIM * ST. MOL. TO CAO
53.
53-
54.
50.
50.
51 .
51.
51*
57.
55.
55.
54.
53-
53.
54.
54.
52.
52.
52.
STONE
53.
53.
48.
48.
48.
53.
53.
53.
51 .
55.
55.
53.
53.
55.
52.
55.
54.
50.
49.
52.
21 .8
22.0
21.3
21.2
21.5
20.9
22.0
23*1
23. 1
23.0
22.8
22.6
22.2
22.6
21 .9
21 .9
21.9
21.8
21.7
CHANGE
21.7
21 .6
21 .8
21 .6
23.2
22.0
22.1
22.0
22. 1
22.6
22.1
22.2
22.3
22.2
22*0
21.8
23. 1
23.2
22*0
21 .9
0.33
0.42
0.48
0.51
0.48
0.69
0.57
0.45
0.57
0.48
0.57
0.51
0.39
0.61
0.59
0.60
0.45
0.48
0.21
1 .01
1. 19
0.90
0.77
0.88
0.89
0.87
0.77
0.93
1.00
0.95
0.71
0.72
0.83
0.72
0.63
0.51
0.63
0.69
0.72
87.3
91 .8
99.5
101 .2
94.2
88.3
104.0
88.7
84.8
88.4
75.3
71 .9
76.4
72.8
89.0
72.5
80.7
69.7
71.8
68. 4
88. 1
82-0
95.8
81 .7
82.6
96.8
102.0
97.5
92-2
93.7
87.9
71.3
88.3
85.9
84.4
79.4
74. 1
77.6
77.6
OF FED
75.4
74.9
73.3
77.2
80.7
76.4
84.9
71 .9
66.2
68. fl
79.6
65.5
72.2
71.5
75.6
68.3
71.7
71 .1
61.9
61 .9
64.4
65.3
69.2
68.7
67.7
69.6
64-3
66*8
65-0
64.3
71.2
62.5
67.2
70.5
69.9
65.7
64.9
66.3
66. 1
- 425 -
-------
RUN 7:
APPENDIX D: TAiLE IV.
DESULPHURISATION PERFORMANCE PAGE 5 OF 10
9.0530
9.0630
9.0730
9.0830
9.0930
9 . 1 0 30
9
9
9.
9
9
9
9
9 . 1 130
9.1230
1330
1430
1530
1630
1730
1830
1930
9.2030
9.2130
9.2230
9.2330
10.0030
10.0130
10.0230
10.0330
10.0430
10.0530
10.0630
10.0730
10.0830
10.0930
SULPHUR GAS
REMOVAL VEL.
% M/S
68.0 .30
68 • 4 .29
68 • 1 .29
67.3 .27
67.0 .25
69.2 .24
SHUT DOWN AT 8
52.5 .38
53.2 .35
54.0 .38
58.0 .33
58.3 .25
61.4 .22
63.7 .32
64.7 .32
68.2 .32
71.3 .30
71.7 .26
71.4 .14
72.0 1.25
70.4 1.21
71.3
72.2
71 .8
71.3
70.4
71.5
69.5
69.3
69.3
69.3
69.3
69.7
70.7
70.8
70.1
• 08
.09
.08
.10
• 09
.12
• 12
.09
.09
. 1 1
• 11
• 12
. 1 1
• 11
.07
G-BED AIR/
DEPTH
CAO/S
FUEL RATIO
CENTIM * ST
53.
53.
50.
50.
52.
53.
• 0830
43.
45.
45.
45.
46.
48.
STONE
48.
49.
53-
53.
53.
53.
50.
50.
48*
50.
49.
50.
49.
48.
48.
48-
48*
48*
48.
50.
48*
46.
48.
22.0
21 .9
21 .9
21 .9
21 .9
22.2
FOR 21
23.2
22.5
23.4
22*8
22.2
21 .0
CHANGE
23.3
24.4
24. 1
25.7
24.8
23.5
25.5
23.3
21 .8
21.9
22.0
22.0
22*0
22.4
22*4
22.0
22.0
22.3
22.4
22.3
22.4
22.4
21 .9
. MOL.
0.78
0.78
0.90
1.47
1 .74
1 .89
HOURS
1.96
2.09
1.81
1.83
1.71
2.23
2.07
3.26
3.72
3.46
3.53
2.70
0.96
• 33
.29
.45
.51
.39
.42
.24
• 32
• 54
• 45
.47
.48
• 44
1 .54
1.57
2.07
X CAS
TO CAO
74.9
73.4
80.5
78.0
77.9
79.7
2.9
46.8
53. 1
53.3
53.6
46.4
54.2
54.8
64.6
66. 1
69.5
79.9
73.7
66*8
70.9
77.7
73.8
74.5
78. 1
70.4
76.6
71 .8
76.4
73. 1
71.3
73.2
72.0
70.4
63.0
RE GEN.
S OUT %
OF FED
67.6
65.9
61.2
67. 4
64.3
63.9
2.8
52.0
53.0
69.6
50.9
50.3
56.0
52.2
56.8
61 .5
55.0
74.3
76.3
61.3
63-6
63.7
63-4
66.7
66.4
66.5
67.0
66.3
70.4
65.2
64.4
66.6
64.5
64.0
58.5
- 426 -
-------
APPENDIX Dt TABLE IV.
RUN 7: DESULPHURISATION PERFORMANCE PAGE
6 OF lO
DAY. HOUR
10.1030
10. 1 130
0.1230
0. 1330
0* 1 430
0.1530
0. 1630
0.1730
0*1830
0. 1930
0*2030
0.2130
0.2230
0.2330
.0030
• 0130
.0230
.0330
.0430
.0530
.0630
.0730
.0830
.0930
.1030
. 1 130
.1230
• 1330
. 1430
.1 530
.1630
• 1730
• 1830
• 1930
.2030
.2130
.2230
.2330
12.0030
SULPHUR GAS
REMOVAL VEL.
Z M/S
70.8
74. S
76.9
75.6
75.2
78.3
78.9
80*0
81*0
82.4
82.0
81.2
80.9
79*6
78*6
77*6
78*2
77.5
77.5
78.6
79.2
79.1
78.8
79.5
78.8
78*3
79.3
79.0
79.0
78.6
79.0
79.6
79.3
79.3
79.6
78.8
76.9
72.9
.13
.12
.10
.07
.09
.10
• 08
• 06
.09
.12
• 1 1
• 12
.12
.11
.1 1
.12
.12
• 12
.12
.1 1
• 1 1
• 12
• 14
• 13
.10
.13
• 15
• 12
• 15
• 16
• 15
• 15
.15
• 15
.15
.20
• 34
.20
73.4 1.23
G-BED
DEPTH
AIR/ CAO/S
FUEL RATIO
CENTIM X ST. MOL.
50.
53.
56.
54.
55.
55.
55.
57.
55.
55.
55.
55.
54*
54.
55rf
55.
55.
55.
55.
55.
57.
55-
55.
57.
57.
57.
58.
60.
59.
58.
58.
58.
58*
58.
58.
58.
50.
48.
STOME
48.
23-0 3.33
23.1 3.28
22.4 3.27
22.3 3.43
22-7 3.40
22.6 3.21
22.2 3.37
22.3 3.64
22.2
22.7
22*6
22.7
22.7
22.6
22.7
22.7
22.6
22.6
22.7
22*6
22.7
22.7
23.2
23.1
22*6
23.1
23.6
23.0
23.5
23.5
23.5
23.5
23.5
23.5
23.6
23.7
.96
.32
• 41
• 35
.51
• 47
• 29
• 30
• 29
• 45
• 51
• 56
• 5t
• 51
.51
• 57
.57
.48
.58
.69
.48
.21
.21
.27
.57
.48
.46
.43
22*0 0.82
21.0 0.06
CHANGE
21.7 1.87
% CAS
TO CAO
74.7
76.3
77.5
74.9
62.2
74.6
75.5
89.0
91 .0
90.7
83«2
89.3
84.8
85.9
83*4
88.3
72.5
67.3
70.4
85.2
79.4
76.9
80.3
80.2
88.2
77.2
93.9
93.7
89.1
93.5
98.4
102.7
75.1
86.6
90.3
76.2
71.6
69.6
68*4
RE GEN.
S OUT *
OF FED
65.9
66.3
66.4
65.0
53-7
63. 1
61.5
65.2
77.5
77.6
77.0
78.5
76.9
76.9
74.0
80*4
64.6
60*2
64.3
79*5
72.6
70.5
73.6
74.8
78.3
69.9
79.8
82.5
77.6
73.0
87.5
92.5
67.8
84.2
88.0
75.2
70.4
73. 1
72.0
- 427 -
-------
RUN 7:
APPENDIX
DESULPHURISATION
D: TA1LE IV.
PERFORMANCE
PAGE 7 OF 1
DAY. HOUR
12.0130
12.0230
12.0330
12*0430
12.0530
12.0630
12.0730
12.0830
12.0930
12. 1030
12. 1 130
12. 1230
12.1330
12.1430
12.1530
12. 1630
12.1730
12.1830
12.1930
12*2030
12*2130
12.2230
12.2330
13*0030
13*0130
13*0230
13*0330
13*0430
13*0530
13*0630
13*0730
13*0830
13*0930
13*1030
13*1130
13*1230
13*1330
13*1430
13*1530
13*1630
SULPHUR GAS
REMOVAL VEL*
% M/S
77.5 .09
79.7 .04
78.7 .04
80*0 .04
81.3 .04
81.9 .04
81.3 .04
83*2 .03
82.8 .01
82.5 0.99
82.8 0*99
83.5 0.99
83*5 0*99
85.9 0.99
84*6 0*99
83*9
83*8
82.6
82.1
82.4
83*6
83.4
83.4
83*3
81*5
78*6
79*5
81*3
82*0
80*7
80*5
81*9
80*0
80.9
82.2
82.5
81.3
81*0
80.4
80.4
.00
.02
.05
.05
.04
• 04
.04
.05
.05
• 10
.11
• 14
• 14
• 14
• 12
• 11
• 14
• 1 1
• 14
.08
.08
.04
• 04
• 04
• 04
G-BED
DEPTH
CENTIM
52.
48*
46*
46.
46*
46.
45.
46.
49.
50.
53.
54.
53.
55.
57.
57.
59.
62*
64.
65*
67.
66.
66*
62.
64*
63.
58*
57.
57.
57.
57.
63*
63.
62.
62.
56.
56.
56.
56*
56.
AIR/
FUEL
% ST.
23. 1
23. 1
23.2
23*2
23*2
23.2
23-2
23.3
23.0
22.5
22.5
22*4
22.6
22*6
22.6
23*2
23.5
24.0
24.0
24.1
23-5
24*3
23*0
23*9
24*9
24*9
25*2
25*3
25.3
24.8
24.6
25*0
24*9
25.7
23.7
24.0
23*0
23.1
23*0
23.2
CAO/S REGEN.
RATIO % CAS S OUT 7.
MOL. TO CAO
2.24
2.42
2.59
2.95
3*03
2.75
2.79
3.22
2.96
2.75
2.08
2.42
2.52
2.42
2.82
2.87
3.38
3*48
3.20
2.70
2.70
3*45
2*97
2*51
2*63
2*82
2*00
2*24
2. 14
2.92
2.29
2.99
2.38
2.45
1.38
1*13
0.75
0.89
0*88
1 .03
68.8
16.2
65.5
74.7
78.2
77.4
78.3
70.3
77.9
63.4
79.7
87.3
82.2
77.0
77*6
74*8
63.4
72.3
72*6
73*7
74.5
79.7
73.6
74*0
74*3
73*0
76*1
63*1
74*5
70.3
69.9
59.0
66*5
62.9
72*1
77*5
73*5
74.3
70. 1
67.7
OF FED
70.3
14.7
69.6
76.2
79.3
74.3
75.6
69.4
72.5
70.9
80. 1
81 .9
75.7
74.6
79-5
81.6
68.3
74. 4
64. 1
71.7
73.5
75.7
69.5
72.6
74.4
73*7
82*7
65.5
76.6
74.2
69.9
58.7
68.1
63*6
72.6
78.9
75.9
75.9
72.2
70.3
- 428 -
-------
RUN 7:
APPENDIX D: TABLE IV.
DESULPHURISATION PERFORMANCE PAGE
R OF 10
DAY. HOUR
SULPHUR GAS G-BED
REMOVAL VEL. DEPTH
% M/S CENTIM
13. 1730
1 3 • 1 8 30
13.1930
13.2030
13.2130
13.2230
13.2330
14.0030
14.0130
14.0230
14.0330
14.0430
14.0530
14.0630
14.0730
14.0830
14.0930
1 4. 1030
14. 1 130
14. 1230
14. 1330
14. 1430
14. 1530
14. 1630
14. 1730
14. 1830
14.1930
14.2030
14.2130
14.2230
14.2330
1 5.0030
15.0130
15.0230
15.0330
15.0430
15.0530
15.0630
15.0730
15.0830
80.9
80.7
79.7
79.1
79.1
78.8
79.1
79.1
78.4
77.5
79.1
78.7
76.1
76.5
77.0
77.7
76.7
76.2
76.2
75.9
76.1
76.3
76.4
76.1
77.7
80.3
77.9
76.6
73.7
75.7
75-2
74.0
74.9
74.7
74.4
74.3
75.5
76.6
77.2
77.7
.05
.06
.06
.06
.07
• 06
.08
• 11
. 1 1
.09
.08
.00
.18
. 10
• 12
• 13
• 13
.10
• 10
.08
.08
. 10
.08
.08
.07
.07
.06
.07
.09
.09
. 10
. 10
.09
.09
.19
.22
.20
• 18
• 19
.17
57.
57.
56.
56.
56.
52.
56.
52.
53.
55.
55.
55.
52.
54.
52.
54.
57.
53.
57.
53.
56.
56.
56.
53.
57.
55.
54.
53-
53.
53.
53.
53.
53*
53.
53-
53.
56.
53.
53.
53.
Alfc/
FUEL
CAO/S
RATIO 2
CAS S
J. ST. MOL. TO CAO
23-8
23.0
23.3
23.2
23.1
23.1
23.2
23.4
23.7
23.2
23.2
22.2
22.4
22.2
22.8
22.9
22.7
22.3
22.2
21 .8
21*8
22.2
21.8
21.7
21 -8
21.8
21.8
21.8
22.1
22* 1
22.5
22.4
22. 1
22.1
22.1
22.9
22.8
22.2
22.4
22.4
.29
.34
.46
.05
.05
.22
• 02
0.91
1 .05
1.05
0.95
0.91
0.98
1 .08
0.94
0.95
0.91
0.98
0.94
0.88
0.95
0.95
0.91
0.94
1.15
1.49
1.11
0.94
1.07
1.11
0.82
0.85
0.98
1.25
1.11
1.19
1.29
1. 18
1.08
1.53
66.7
70.3
64.9
75.4
74. 1
74. 1
74.2
72.7
70.6
68.4
70.6
70.7
71 .4
74.0
76.8
72.3
74.0
74.0
79.1
73.0
75.4
72.9
74.6
71.5
70.9
75.4
78.9
78.9
79.4
77. 1
84.5
87.2
89.4
73.6
64.3
68.3
68.0
67.0
68. 1
70.9
RE GEN.
OUT *
OF FED
69.5
66.8
63.2
74.5
76.?
76. 1
77.9
71.5
67.7
65.9
71.1
78.9
68.6
74.8
74.4
70.3
71.5
69.7
74. 1
72.1
72.5
66.6
70.2
63. 1
64.0
62.5
72.0
70. 1
68.9
68.7
74.0
73.0
83.1
69.6
63-3
61 .7
59.7
59.4
60.0
61 .3
- 429 -
-------
RUN 7:
APPENDIX D: TAiLE IV.
DESULPHURISATION PERFORMANCE PAGE
9 OF 10
DAY. HOUR
15.0930
15. 1030
15. 11 30
15. 1230
15. 1330
1 5. 1430
15.1530
15. 1630
15. 1730
15. 1830
15. 1930
1 5.2030
1 5.2130
15.2230
15.2330
16.0030
16.0130
16*0230
16.0330
16.0430
16.0530
16.0630
16.0730
16.0830
16.0930
16*1030
16.1130
16. 1230
16. 1330
16. 1430
16* 1530
16*1630
16* 1730
16. 1830
16*1930
16.2030
16.2130
16.2230
16*2330
17.0030
SULPHUR GAS
REMOVAL VEL.
% M/S
77.1
77.4
79.1
80.4
78.6
79.6
79.7
79.9
78.2
77.7
76.9
76.8
77.2
76.5
78.5
78.5
77.7
79.9
78.5
76.3
77.0
77.1
78.4
78.6
• 12
.21
. 19
• 21
.20
. 18
• 16
• 13
.15
.13
• 16
• 12
• 14
.1 1
• 12
• 12
.21
. 10
• 10
• 10
• 18
.09
.08
.07
78.8 0.99
78.5 0.99
78*6 0.98
79.5 0.96
78.8 0.95
78.4 0.96
78*4 1.00
78.1 0.95
78*1 1.01
78*8 1.00
79.1 0.99
77.6 0.96
77.0 0.96
74.0 0.97
72.3 0.97
72.0 0.97
G-BED
DEPTH
CENTIM
55*
58.
58.
55.
58.
57.
57.
57.
57.
57.
56*
56.
56.
53.
54*
56.
56.
56.
56.
56.
56.
56.
56.
54.
57.
57.
55.
55.
58.
60.
57.
57.
60*
60*
57.
60*
60*
60.
57.
58.
AIR/ CAO/S
FUEL RATIO
Z ST. MOL.
22.2 1.31
22.7 .28
22.3 .42
22.7 .39
22.7 .15
22.7 .35
22-2 .28
21.8 .19
21.7 .28
21.7 .25
21.8 .12
21 .7 .45
21.8 .22
21.5 .19
21.8 .39
21.8 .15
24*0 .10
23*6 .26
23.6 .29
23.6 0.81
25.5 0.98
23.5 1.11
23*6 1.05
23.7 0.99
21.8 .29
21-7 .22
21.7 .15
21.3 .15
21.2 .15
21.2 0.91
21.7 0.91
20.5 .21
21.8 .28
21.7 .00
21*6 0.91
20.8 .11
20.8 .25
20.8 0.91
20*8 1*04
20.7 0.98
% CAS
TO CAO
67. 1
71 .8
78.8
82.5
78. 1
78.5
79. 1
77.8
73.8
70.7
65.2
66. 1
57.0
66.8
63.5
65.7
76.6
79.6
78.2
85.6
87.9
87.8
95.2
96.0
94.3
80.0
92*2
87.8
89. 1
90.5
89. 1
86.2
87.9
92.7
89.1
85.2
79.5
73.5
73.4
74.0
REGF.N.
S OUT X
OF FED
60.0
61. 1
66.0
88*3
92.3
89.0
87.5
89.5
84.3
82. 1
F54.8
70. 1
67. 1
74.4
72.0
68.8
92.3
83.9
81.9
93. 1
85.3
80.5
81. 1
79.8
76.0
72.2
75*5
70.5
73-5
75.7
73.9
72.1
69*8
73. 1
70.8
73.0
74.6
73.3
75.4
77.1
- 430 -
-------
RUN 7l
APPENDIX D: TABLE IV.
DESULPHURISATION PERFORMANCE PAGE
10 OF 1O
3AY
.HOUR
SULPHUR GAS G-BED
REMOVAL VEL. DEPTH
3 M/S CENTIM
17.
17.
17.
17.
17.
17.
17.
17.
17.
17.
17.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
0130
0230
0330
0430
0530
0630
0730
0830
0930
1030
1 130
1230
1330
1430
1530
1630
1 730
1830
1930
2030
2130
71.6
70.9
74.6
72.3
73.0
73.6
74.4
74.7
.02 58.
.02 58.
•01 54.
.07 54.
.01 57.
.02 56.
.01 53.
.01 57.
75.4 0.92 54.
74.7 0.94 52.
73.6 0.93 54.
73.6 0.91 54.
73.7 0.91 54.
73*6 0.91 54.
73-1 0.88 54.
75.7 0.86 55.
76.5 0.86 58.
76.3 0.88 54.
76.4 0*86 54*
76.4 0.86 54.
76.4 0.85 53.
AIR/
FUEL
CAO/S RE GEN.
RATIO % CAS S OUT *
% ST. MOL.
20
20
20
20
20
20
20
20
19
20
20
20
20
20
20
20
20
21
20
20
20
.7
.6
.6
.5
.7
• 6
.6
.6
.8
• 3
• 2
. 1
. 1
.3
. 1
.5
.8
. 1
• 8
*7
.8
0
0
0
0
0
0
1
1
1
0
0
1
1
0
1
1
2
2
1
1
1
•
•
•
•
•
•
•
*
•
•
•
•
*
•
•
•
•
•
•
•
»
TO CAO
98
84
71
87
98
91
1 1
28
01
61
94
01
07
78
45
97
03
09
32
07
32
67.7
68.2
82.8
69.4
71 .8
76. 1
78.8
75.2
84.7
90.3
93.2
83.6
91 .0
85.3
84.9
75.5
82.7
83. 1
80-3
8L6
72.4
OF FED
67
69
81
66
64
63
80
59
67
69
67
67
71
76
7?
69
74
79
78
74
68
.9
.9
• 4
.8
• 1
.9
.4
.2
.4
.9
.4
.4
.5
.0
.3
.0
.7
. 1
.6
. 1
.5
- 431 -
-------
RUN
APPENDIX D: TABLE V.
7: GAS COMPOSITIONS
PAGE ! OF 6
10
I
DAY.HOUR
• 1230
• 1330
• 1430
• 1530
• 1630
• 1730
• 1830
• 1930
• 2030
• 2130
• 2230
• 2330
• 0030
0130
0230
0330
0430
0530
0630
0730
0830
0930
2.
2.
2.
2.
2.
2.
2.
2.
2.
2.
2. 1030
2.1 130
2.1230
2-1330
2.1430
2.1530
F L
02
X
4.6
5.0
3.5
5.0
2.0
2.5
.5
.4
.2
• 4
.0
.2
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.1
2.0
2.0
2.0
1.9
1 .9
1.9
1 .9
U E GAS
C02 VOL X
ANAL CALC
11.9 12.3
11.2 12.0
12.4 13.2
1 1.4
13.2
13*0
13.8
13.5
13.8
13.8
14. 1
14.1
13.5
13.8
13.8
13.8
13.8
13.8
13.5
13.5
13.5
13.5
13.8
13.8
13.8
13.5
13.5
13.8
12.1
14.3
13.9
14.6
14-7
14.9
14.7
15.0
14*8
14.3
14.3
14.3
14.3
14.3
14.3
14*3
14.3
14.2
14.3
14.3
14.3
14.3
14.4
14.4
14*4
REGENERATOR GAS
S02 02 C02 S02
PPM XXX
1008. 1.10 0.5 2.7
1008. 6.00 0.2 0.3
606. 3.00 0.4 1.5
908. 2.00
757.
757.
808.
768.
753.
743.
733.
747.
767.
687.
606.
621.
571.
556.
505.
490.
465.
.50
.20
.60
.00
.00
.00
.00
• 00
.00
.00
.00
.00
.00
.00
.00
.00
.00
445. 1.00
394. 1.00
389. 0.90
374. 0.90
334. 1.00
349. 0.90
394. 1.00
0.8
• 0
.0
.2
• 3
.6
0.6
2. 1
2.1
2.2
1.7
2.3
1 .4
1 • 1
2.0
3.3
1 .0
0.8
2.3
2.4
1 .7
3-0
2. 1
2.0
1 .6
2.7
3.5
4.2
4.0
4.6
5.4
5.0
7.4
5.6
7.4
6-2
6.2
5.4
5.8
7.0
7.6
5-4
5.2
6.6
6.8
7.4
7.6
8.0
7.6
7.?
GASIFIER
02 VOL X
ANAL CALC
16.9 16.5
15.5 16.4
15.0 15.8
1
1
1
1
1
1
1
1
1
1
1
1
1
1
I
1
1
1
1
1
1
1
1
1
1
5.0
6.0
6.5
6.1
6.1
5-9
6.3
6.3
6.5
6.8
6.8
6*8
6.8
7.0
7.0
7.0
7.2
7.3
7.3
7.2
7.2
7.4
7.5
7.6
7.7
16*1
16.3
16.8
15.9
16.1
17.0
17.3
17.1
17.4
17.5
17.4
17.5
17.5
17.5
17.8
17.8
17.8
17.9
18*0
17.9
18.2
18. 1
18. 1
18.3
18.4
INLET GAS
C02 VOL X
ANAL CALC
3.27 3.24
3.92 3.24
4.02 3.72
4.02
3* 10
2.84
3.01
2.93
3. 10
2.76
2.68
2.60
2.44
2.44
2.44
2.36
2.28
2.12
2.12
2. 12
2. 12
2. 12
2.12
2.12
2. 1?
2.04
1 .96
1 .96
3*48
3.26
2.93
3.62
3.4*
2.75
2.59
2.73
2.56
2.50
2.60
2.55
2. 55
2.54
2.33
2.27
2.31
2. 19
2.13
2.22
2.06
2.09
2.04
1.93
1 .89
-------
CJ
OJ
2« 1630
2-1730
2.1830
2*1930
2*2030
2.2130
2-2230
2.2330
3*0030
3*0130
3*0230
3*0330
3*0430
3.0530
3*0630
3*0730
3*0830
3*0930
3.1030
3 • 1 1 30
3.1230
3*1330
3*1430
3.1530
3.1630
3*1730
3*1830
3*1930
3.2030
3.2130
3*2230
3-2330
4.0030
4.0130
4.0230
4*0330
1 .9
2.0
2.0
2*0
2.0
2.0
2.0
2.0
1 *7
3.0
.5
.3
.3
.5
.8
• 6
.9
.9
.9
2.0
1.9
2*0
2*0
2*1
2. 1
2.0
2*0
2*1
2. 1
2.4
2.4
2.1
1 .8
2.0
1.8
1*8
13.8
13*8
13.8
13.8
13*8
13.8
13.8
13*8
13.8
13-2
14. 1
14. 1
14. 1
14.1
13.8
13.8
13.8
13.8
13.8
13.5
13-8
13.5
13.5
13*5
13*8
13*8
13.5
13.5
13.5
13.5
13.5
13*5
13.8
13*8
13.8
14*1
14*4
14.3
14*3
14*3
14*3
14.3
14.3
14*3
14*5
13*5
14*7
14*8
14*8
14*7
14*4
14*6
14*3
14.4
14.4
14*3
14*3
14*3
14*3
14.2
14*2
14*3
14*3
14*2
14.2
14.0
14*0
14*2
14*5
14.3
14*5
14*5
455.
490.
490.
510.
500.
465*
434.
404.
404.
419.
414.
399.
379.
369.
354.
369.
384.
384.
364.
364.
359.
334.
313.
313.
293.
303.
288.
278.
273.
263.
263.
263.
263.
273.
298.
308*
0.90
1 .00
1*30
1.00
1.00
1.00
0.20
0.20
0.
0.
0.
0.
0*
0*
0*
0*
0*
0.
0.
2.00
0.
0.
0.
0*
0.
0.
0*
0*
0.
0.
0*
0*
0*
0.
0*
0*
.9
.9
• 2
• 3
.9
3.1
3.1
3*0
3*1
5*2
2.6
2.9
3*1
2*9
2*4
2*3
2*0
1 .8
2.2
1*5
2*4
2*8
3*5
2*1
2*3
2.2
2*6
3*0
2*5
2.5
2*6
3*9
4.0
3-9
5.0
6*8
8.8
7.6
7.0
7.4
6*4
6.2
6*2
7*0
6*6
7*4
7*0
7.4
7.4
7.4
7*0
7.0
7.4
7.2
7.2
6*6
7.6
7.0
8.0 1
8*2 1
8*2 1
8*2 1
8*8 1
7.8 1
7*6 1
6*6 1
8*0 1
7.4 I
7.8 !
7.2 1
7.8 1
7.8 1
7.7 18.4 1.88 1.87
7.7 18.3 1.81 1.93
7.1 17.8 2.28 2.35
7.2 18. 1 2.20 2. 1 3
7.2 18.2 2.20 2.05
6.9 17.6 2*44 2*46
7-1 17.8 2.44 2.31
7.0 17.7 2.44 2.36
7.2 18.0 2.28 2. 1 1
7*2 18.1 2.28 2.16
7.2 17.9 2-28 2.27
7.2 17.7 2.60 2.34
7.2 18*0 2*12 2. 14
7.0 17.9 2.28 2.23
7.1 18.0 2.28 2.13
7.2 17.8 2*20 2.30
7.2 18.0 2. 12 2. 14
7.4 18. 1 2.12 2.09
7.4 18. 1 2. 12 2.09
7*4 18*2 2* 12 2*03
7.3 18.2 2.20 2.04
7.9 18.4 .81 .88
8*0 18*3 *65 .90
18.0 18*6 .81 .71
8.4 18.4 .49 .90
8*6 18.6 .49 .74
8.6 18.6 .33 .71
18.6 18-6 .33 .72
18.8 18.8 .24 .57
19.0 19.0 .16 .45
19*0 19*0 .16 *45
9.0 19.0 -16 .43
19.2 19.2 0.99 .29
18.0 18»6 .96 .73
9.0 19.0 .33 .44
19.2 19*2 .16 .32
-------
RUN 7:
GAS COMPOSITIONS
PAGE 2 OF 6
CO
I
DAY.HOUR
4.0430
4.0530
4.0630
4.0730
4.0830
4.0930
4.1030
4 . 1 1 30
4.1230
4.1330
4.1430
4.1530
4.1630
4 . 1 7 30
4.1830
4.1930
4-2030
4-2130
4.P230
4.2330
5.0030
5.0130
5.0230
5.0330
5-0430
5.0530
5.0630
5.0730
F L
02
*
P.0
2.0
3.0
2.0
2.0
• 8
.6
.7
.7
.5
.7
.6
-8
.9
.9
?.0
2.0
2.0
?.0
?.0
1 .8
?.0
?.0
?.0
>.4
3.0
1 -9
3.0
U E GAS
C02 VOL I
ANAL CALC
13.8
13.8
13.8
13.8
13*8
13*8
13.8
13*8
13.8
13.8
13*8
13-5
13*5
13.5
13.5
13.5
13.5
13.8
13*8
13*8
13.8
13.8
13-8
13.5
1 3.2
13.5
13.5
13. R
4.3
4.3
4.3
4.3
4.3
4.5
4.6
4.5
4.5
4.7
4.5
L4.6
4.5
4. 4
4.4
4.3
4.3
4.3
4.3
4-3
4.4
4.3
4.3
4.3
4.0
4.3
4*4
4.3
REGENERATOR
S02
PPM
328.
364.
323.
288.
293.
313-
323.
344.
369.
369.
354.
354.
334.
354.
344.
323.
308.
283.
273.
273-
233-
268.
303.
303.
293-
283.
283-
293.
02
%
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
w.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
C02
I
6.4
5.4
3.7
4.3
4.0
4.7
4.4
6.9
5.2
4.7
5.0
3.9
3* 1
6.4
2.6
3. 1
2.0
5.4
5.9
7.8
5.9
5.2
6.7
2.7
1 .9
3.8
2.8
3. 1
GAS
S02
X
7.4
6.6
7.2
7.6
7.8
8*0
7.4
7.2
7.0
7.4
7.0
7.8
8.2
7.4
7.4
7.4
7.2
7.0
6.6
7.0
7.0
6.6
7.6
7.6
7.4
7.6
7.8
8.2
GASI
FI
02 VOL
ANAL
19.0
19.2
19.2
19.2
19.2
19.2
19.2
19.2
18.0
18.2
18.0
18.0
18.2
1 7.8
18.4
18.4
18.6
18.8
18.8
1R.8
18.8
19.0
20.0
20.0
20.0
20.0
20.2
20.0
ER INLET GAS
% C02 VOL t
CALC ANAL CALC
19
19
19
19
19
19
19
19
19
19
19
19
19
1R
18
18
18
19
19
19
18
18
19
18
19
19
19
19
•3 1.16
.3 1.08
•3 1.08
•3 1.08
•3 1 • 08
•3 1.08
.2
• 3
• 3
.0
. 1
• 1
.2
.8 {
.7
.7
.7
.0
• 0
.0
.9
.9
.08
.08
.08
.81
.81
.81
• 65
>*04
.57
.49
.41
•24
• 16
• 16
.08
.08
.0 0.34
.9 0.34
• 0 ft . 3/i
•3 0.34
.3 0.34
•3 0.23
.22
.22
• 24
.2*
-24
.24
.24
.24
.22
.43
.38
• 34
.27
.57
.63
.63
.63
.44
.45
.48
.54
.55
.49
.48
.45
• 24
.22
. ?4
-------
en
I
5.0830
5.0930
5. 1030
5. 1 130
5. 1230
5. 1330
5. 1430
5. 1530
5. 1630
5 • 1 7 30
5. 1830
5. 1930
5.2030
5.21 30
5.2230
5.2330
6*0030
6*0130
6-0230
6-0330
6*0430
6-0530
6*0630
6-0730
6*0830
6*0930
6* 1030
6- 1 130
6* 1230
6* 1 330
6* 1 430
6-1530
6* 1630
6. 1730
6« 1830
6. 1930
2.0
2.0
2.0
2.0
2-0
2-0
2-0
1 -9
1 .8
1 «9
1 .6
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.0
• 8
.8
.8
.8
-8
-8
.8
.5
• 8
.3
.8
.9
.0
.2
.0
6* 1
2.1
13.8 14.3
13.5 14.3
13-5 14.3
13-5 14.3
13.5 14.3
13*5 14-3
13-5 14-3
13-5 14-4
13-8 14.5
13-8 14.4
13*5 14.6
13*5 14.3
13-5 14-3
13.5 14.3
13«5 14-3
13.5 14.3
13*2 14.3
13»5 14.3
13.2 14*3
13.5 14.5
13*2 14.5
13-2 14.5
13-2 14.5
13.2 14.5
13-5 14.5
13.2 14.5
13.2 14.7
13.0 14.5
13.5 14.8
13.0 14.5
13.0 14.4
13.5 15.1
13-2 14-9
13.2 15* 1
13*2 1 1 -2
12.4 1 4.3
303-
303-
303-
303.
308*
308.
313*
313.
318.
313.
313.
313.
323-
323.
323.
379.
374*
384.
394.
389.
389.
384.
379.
394.
394.
384*
384.
364-
415-
429-
435-
455.
475-
495-
483-
469-
f*.
0.
0.
0.
0.
0.
0*
0.
0.
0*
0-
0*
0-
0.
0-
0-
0.
0.
0.
0.
0.
0.
0.
0.
0.
0-
0.
0.
0.
0.
0-
0.
0.
0.
0.
0-
5.0
4.7
3.9
3.1
3.7
3-7
4. 1
2-6
4-1
7*2
4- 1
5.0
4. 1
4-7
5- 1
1 .9
4-3
5-0
2.2
2.5
3* 1
2.8
2-5
2.5
2.1
4.5
3.0
2.6
3-0
3-7
5-2
5.2
3-3
3- 1
5-7
3.5
7-6
7.4
7.8
7.6
7.8
7.8
7.8
8-2
8.6
8*6
8.4
9.4
8.2
8-8
10.7
7.8
10.5
7.8
9.0
9.2
9.2
9.4
9.0
9-6
10.3
10.3
10.3
10.3
9.9
9.6
9.4
9.6
10.3
9.9
9.4
9.4
20.0
20.0
20.2
20.2
20.2
20.2
20*2
20*4
20.4
20.6
20*6
20.8
20.2
20.2
20.2
20.2
20.2
20-2
20.2
20.2
20.2
20.2
20.2
19*6
19.0
18*0
18-2
19.8
7-0
7.5
7.2
7.3
7.5
7.5
7.5
8.8
19.3
19.3
19.3
19.3
19-3
19-3
19-2
19.2
18*9
19-2
18.5
18-5
18*9
18-9
19*2
19*2
19-3
19-3
19.3
19.2
19-2
19-2
19-2
19.4
19.4
19.4
19.7
19.7
18.0
18.3
18.2
18.0
18.1
18.3
19.5
19.8
0. 23 1 .?7
0. 13
0. 13
0- 13
0-23
0-23
0-23
0.23
0. 13
0-02
0.02
0.02
0.23
0.23
0.23
0.23
0.23
0.23
0.23
0.23
0.23
0.23
0.23
0.63
1.41
1.33
.?2
.?4
.23
• 23
• 24
.27
.27
. 51
.30
. 72
.81
.52
. 49
.25
.26
-21
.23
• 21
-25
.23
.21
-21
• 1 1
- 1 3
• 1 1
1 . 16 0.89
0.81 0-87
2.60 2.03
2-28 1.80
2.44 1 .9?
2.36 2.00
2.28 «94
2-1? 1.76
2-12 1 .29
1 .2^ 0«8 1
-------
RUN 7:
GAS COMPOSITIONS
PAGE 3 OF 6
DAY.HOUR
10
6.2130
6.2230
6.2330
7.0030
7.0130
.0230
• 0330
.0430
.0530
.0630
7
7
7
7
7
7.0730
7.0R30
7.0930
7.1030
7. 1130
7.1230
7.1330
7.1430
7.1530
7.1630
7. 1730
7.1830
7.1930
7.2030
7 . 21 30
7.2230
F L
02
X
.5
.5
.3
.3
.5
.5
.6
.8.
.8
.8
.2
.4
.5
.4
.5
• 3
• 3
.2
• 2
.5
.5
.5
.5
.5
.8
.8
.8
U E GAS
C02 VOL *
ANAL CALC
13.2
13*0
13.2
13-0
13.0
13.0
12.7
12-7
12.7
12.7
13.0
12.7
13.0
13.0
13.0
13.0
13*0
13.0
13-2
13.0
13. 1
13. 1
12.7
12.7
13.0
13.0
12.7
4.7
4.7
4.9
4.9
4-7
4.7
M«6
4.5
4.5
4.5
5.0
SO 2
PPM
459.
470.
485.
500.
515.
500.
505.
500.
505.
535.
560.
REGENERATOR GAS
02 C02 S02
X
0.
0.
0.
0.
0.
0.20
0.
0*
0.
0*
0.
%
4.3
3.7
1 .6
3.1
3.0
2.2
5.0
3.0
4.3
1 .7
4.3
%
8.4
9.2
9.2
7.8
8.2
8.2
8.2
7.8
7.8
8.2
7.0
STONE CHANGE
4.8
4.7
4.8
4.7
4.9
4.9
4.9
4.9
4. 7
4.7
4.7
4.7
4.7
4.5
4.5
4.5
565.
550.
530.
510.
515.
515.
515.
515.
515.
515.
515.
510.
495.
475.
454.
475.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
2.0
4.9
3.7
5.2
3.3
3.3
4. 7
6.3
6*4
6.2
6.2
5.0
3-5
5.9
4. 7
4.6
7.8
8.0
8.2
8.6
8.6
8.6
9. Pi
8-2
7.8
7.8
7.4
8.?
7.4
7.8
7.8
7.R
GASIFIER INLET GAS
02 VOL % C02 VOL %
ANAL CALC ANAL CALC
18-9
18.9
18.5
18.3
18.5
18.3
18.5
18.2
18.2
18.4
18.5
18.7
18.7
18.6
18.R
18. B
18.8
17.PI
18-
IB.
1R.
18.
18.
18.
18.
18-2
18. 4
19.7
19.4
19.3
19.0
19.3
19.3
19.4
19.4
19.4
19.4
19.3
19-3
19.3
19.3
19.4
19.7
19.7
19.7
19.4
19.4
19.4
19.4
19
19
19
19
.08 0
.24
.57
.49
.57
.57
.49
• 65
• 57
.49
49
19.4
1 .49
1 .49
1 .49
1.33
1.33
.33
• 81
• 81
.65
.81
.65
.65
.65
.65
.65
.65
.07
• 1 1
.29
. 10
. 10
.08
.09
.09
.09
. 1 1
09
12
1 .09
1 .08
0.86
1 .PI7
1 -PI4
1 .05
PI.96
1 .08
1.11
1 .PI9
-------
7.2330 £
8.0030 ?
8.0130
8.0230
8.0330
8.0430
8-0530
8*0630
8.0730
8.0830
>.0
>.0
.8
.9
.8
• 6
• 8
• 8
.8
.7
12.7
12.7
12.7
12.7
12.7
12.7
12.4
12.4
12.7
12.7
4. 4
4.3
4.5
4.4
4.5
4.6
4.5
4.5
4.5
4.5
469-
464.
485.
490.
480.
480.
480-
490.
495.
464.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
4.3
3. 1
3. 7
3-7
2.6
2.6
4. 7
3. 1
3.7
3.9
7.6
7.8
7.8
7.8
8.2
8.0
7.4
8.2
7.8
8.0
18.2
18.2
18.2
18.2
18. 1
18.1
18.1
18. 1
18.2
18.5
19.4
19.4
19.4
19.4
19.4
19.4
19.4
19.4
19.4
19.4
.65
.65
.65
.65
.65
• 65
.65
.65
• 65
• 57
.09
.09
.08
.08
.08
.08
.07
.07
.09
1 .07
SHUT DOWN AT 8.0830 FOR 21 HOURS
•r*.
u>
-j
9.0530
9-0630
9.0730
9.0830
9.0930
9. 1030
9 • 1 1 30
9. 1230
9. 1330
9. 1430
9.1530
9. 1630
9. 1730
9. 1830
9-1930
9.2030
9.2130
9.2230
9.2330
10.0030
10.0130
3.0
2-5
3.0
2.5
2-8
2.8
2.4
2.0
2.0
2.0
2.2
2.0
1 .8
1 .6
1 .4
2.0
2.0
2. 1
2. 1
2.0
2.0
13.0 13.5
13.0 13-9
13.0 13.5
13.0
13-0
12.7
13.0
13.0
13.0
12.7
12.4
12-2
12.2
12.2
12.2
11.7
11*4
1 1 .0
1 1 .0
3.9
3.7
3.7
666.
676-
646*
606.
591.
545-
0.
0.
0.
0.
0.
0.
0.0
0.5
0.6
.0
• 6
.0
0.3
5.8
6.6
6.6
6.2
5.6
16.5
17.0
17.1
17.2
17.6
17.2
17.5
18.0
18.1
18.0
18.2
17.7
3-36
2.93
2.76
2.76
2.52
2.76
2.49
?.09
2.09
2. 10
2.00
2.32
STONE CHANGE
4*0
4.3
4.3
4.3
4. 1
4.3
4.5
4.7
4.8
4*4
4.4
4.3
4.3
10.7 14.4
10.7 1 4.4
525.
520.
469.
424.
41 4*
424.
419.
449.
439.
41 4.
419.
424.
439.
42^.
454.
0.
0.
0.
0.
0.
0.
0.
0*
0.
0.
0.
0.
0.
0.
0.
.7
.7
3.0
2.2
4.5
2.4
0.7
1 .6
2.8
4. 1
3.5
3.0
3.6
2.2
3.3
6.2
6.4
6.8
7.4
6*4
8.8
9.0
7.6
7.4
7.4
7.4
7.8
7.8
7.8
7.8
1 7.4
18.7
18.4
19.6
19.6
21 .0
21 .0
21 .0
21 .0
21 .0
21 .0
21 .0
?1 .0
21 .P
21 .0
17.9
18.8
19.4
19.5
19.5
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
2PI.7
2.52
1.73
1.33
1.16
1.08
0.02
0.02
0.02
0.02
0.02
0.02
0.0?
PI. 02
0.0?
-------
RUN 7:
GAS COMPOSITIONS
PAGE 4 OF 6
U)
00
DAY.HOUR
10.0230
10.0330
10.0430
10.0530
10.0630
10.0730
10.0830
10.0930
10.1030
10.1130
10.1230
10.1330
10.1430
10.1530
10.1630
10.1730
10.1830
10.1930
10.2030
10.2130
2230
2330
.0030
.0130
.0230
.0330
.0430
.0530
10.
10.
1
F L
02
X
2.
2.
2-
2.
2.
2.
2.0
2.0
2-0
2.0
2.0
1 .9
2.0
2.0
3.2
2.0
2.0
2-0
2.0
2-1
2- 1
2.0
2.0
2.0
2. 1
2.1
2. 1
2.0
U E GAS
C02 VOL X
ANAL CALC
10.7
10.3
10.3
10.0
9.8
9.8
9.8
9.8
9.8
9.8
9.8
9.8
9.8
9.6
9.0
9.4
9.4
9.2
9.4
9.2
9-2
9.2
9.2
9.2
9.2
9.0
9.0
9.0
4.3
4.3
4*3
4.3
4.3
4.3
4*4
4.3
4.3
4.3
4.3
4.4
4.3
4.3
3.4
4.3
4*4
4.4
4*4
4.3
4.3
4.4
4.4
4*4
4.3
4.3
4.3
4.4
REGENERATOR
502
PPM
454.
454.
454.
454.
449.
434.
434.
444.
434.
374.
343*
364.
369.
323.
293.
298.
283.
263-
268.
278-
283-
303-
318.
333.
323.
333.
333.
31«.
02
X
fl.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
PI.
0.
C02
7.
2.5
2-7
3.0
2.7
2.8
2.8
2.9
2.1
3.0
3. 1
3*3
2-9
2.4
3-0
3-3
5. 1
3-6
3-5
2.3
3. 1
2.R
2.8
2.8
2.6
2.3
2.2
2.2
?.3
GAS
502
X
7.8
8.2
7.6
7.6
7.8
7.6
7.4
7.0
7.8
7.8
7.8
7.8
6.6
7.8
7.4
7.6
9.0
9.0
9 .0
9.0
8-8
R.8
8.4
9.0
7.4
7. Pi
7.2
8 .«
GASI
FIER
02 VOL 1
ANAL
21 .0
21.0
21 .0
21 .0
21 .0
21 .0
21 .0
21 .0
21 .0
21 .0
21 .0
21 .0
21 .0
21 .0
21 .0
21 -0
21 .0
21 .0
?1 .0
21 .0
21 .0
?1 .0
?1 .P»
21 .0
21 .0
21 .0
21 .0
21 .0
CALC
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20. 7
20. 7
INLET
GAS
C02 VOL X
ANAL
0.02
0.02
0.02
0.02
0.02
0.02
0.02
0.02
0.02
0.02
0.02
0.02
PI. 02
0.02
0.02
PI. 02
0.02
PI.02
0.02
0.02
Pl.02
0. 02
PI. 02
0.02
Pi.02
Pl.02
PI. Pi?
0.0?
CALC
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0*
0.
0.
0 *
0.
0.
0.
0 *
0 .
0.
0.
0.
0 .
0.
0.
0.
8
7
7
7
6
6
7
6
5
6
6
6
6
5
5
5
5
5
5
5
5
5
5
5
5
4
4
4
-------
U)
VO
1 1 .0630
1 .0730
1 .0830
1 .0930
1 .1030
1 .1130
1 .1230
1 .1330
1 .1430
1 .1530
1 .1630
1 .1730
1 .1830
1 . 1 9 30
1 .2030
1 .2130
1 .2230
1 .2330
12.0030
12.0130
12.0230
12.0330
12.0430
12.0530
12.0630
12.0730
12-0830
12.0930
12. 030
12. 130
12. 230
12. 330
12. 430
12. 530
12. 630
2. 1
2.2
2-1
2. 1
2.1
2.0
2.0
2.0
2.0
2.0
2.0
2-0
2.0
2.0
2.0
2.1
2.0
2.0
2.3
2.3
2.2
2.2
2.0
2.0
2.0
2.0
2.1
2. 1
2.0
2.0
2.0
2.0
2.0
2.0
2-0
9.0 14.3 308. 0. 2.3 8.0 21.0 20.7 0.02 0« 4
8.8 14«2 308. 0. 2.2 8.0 21.0 20.7 0.02 0. 4
9.0 14.3 313. 0. 2.2 8-2 21.0 20.7 0.02 0- 4
9.0 14.3 303. 0. 2.0 8.4 21.0 20.7 0.02 0. 4
9.0 14.3 313. 0. 2.6 8.4 21.0 20.7 0.02 0. 4
9.0 14.4 323. 0* 2.2 8.2 21.0 20.7 0.02 *• 4
9.0 14.4 308. 0. 3.1 8.4 21.0 20.7 0.02 0. 4
9.0 14.4 313. 0» 2.6 8*6 21.0 20.7 0.02 0. 4
9.0 14.4 313. 0. 2.5 8.2 21.0 20.7 0.02 0. 4
9.0 14.4 318. 0« 3.1 8-2 21.0 20*7 0.02 «• 4
9.0 14.4 313. 0. 2.6 9.0 21.0 20.7 0.02 *• 4
9.0 14.4 303. 0. 2.6 9.4 21-0 20.7 0.02 0. 4
9.0 14.4 308. 0. 1.9 8.2 21-0 20.7 0.02 0. 4
9.0 14-4 308. 0. 2.2 9.9 21.0 20.7 0.02 *• 4
9.0 14.4 303. 0« 2.8 9.9 21-0 20.7 0.02 0- 4
9.0 14-3 313. 0» 2.0 8.6 20.0 18.9 0.81 ««99
9.0 14.3 344. 0. 1.9 8«2 18.0 17.6 0.99 1-60
8.8 14.4 404. 0. 1.9 8.0 17.6 18.9 2*60 fl«96
STONE CHANGE
8.8 14.1 394. 0. 2.4 7.6 18.6 19.0 1.88 »«95
8.8 14.1 333. 0. 2.0 7.8 20.4 18.9 0.63 1*00
8.8 14-2 303. 0. 1-6 1 .8 21.0 18.5 0.02 1«18
8.8 14.2 318. 0» 1»3 7.8 21.0 18*8 0.13 1.04
8-8 14-3 303. 0« 2.3 8.6 21.0 20.7 0.13 •• 1 5
9.0 14.3 283. 0. 1-9 8.8 21.0 20.7 0.02 01.15
8.8 14-3 273. 0. 2»5 8.6 21-0 20.7 0.02 ».15
8.8 14.3 283. 0. 2.4 8.8 21*0 20.7 0.02 0.15
8.8 14.2 253« 0- 1 »8 8-2 21-0 20.7 0.02 0.15
8.8 14.2 258. 0. 3. 3 8»? 21.0 20.7 0.02 0.15
3.0 14.3 263. 0» 1-0 7.8 21.0 20.7 0.02 0.23
3.0 14.3 258. 0. 3-1 8.6 21.0 20.7 0.02 0.23
3.0 14.3 248. 0. 4.1 8.6 21.0 20-7 0.02 0.?3
3.0 14.3 248. 0. 4.1 8.2 21.0 20.7 0.02 0.?3
3.0 14.3 212. 0. 3.1 8.2 21.0 20.7 0.02 P».P3
3.0 14.3 232. 0. 3-3 8.? 21.0 20.7 0.02 0.P3
3.0 14.3 243. 0. 3.4 7.8 21.0 20.7 0.02 0.?2
-------
RUN 7:
GAS COMPOSITIONS
PAGE 5 OF 6
o
I
DAY.HOUR
12.1730
12.1830
12.1930
12.2030
12.2130
12.2230
12.2330
13.0030
13.0130
13.0230
13.0330
13.0430
13.0530
13.0630
13.0730
13.0830
13.0930
13.1030
13.1130
13.1230
13.1330
13.1430
13-1530
13-1630
13.1730
13.1830
13.1930
13.2030
F L
02
2.2
2.0
2.2
2. 1
1 *6
1 .5
1 -8
1 *8
2.0
2.2
2.2
• 8
• 8
• 8
*6
.6
• a
• 6
.2
. 1
• 0
.0
3-9
1.9
1.8
I .4
.4
• 6
U E
C02
ANAL
13.2
13.0
13.0
13.0
13.5
13*6
13- 5
13.5
13-2
13.2
13-2
13.2
13.2
13.2
13-5
13.5
13.5
1 3.2
13.2
13.5
13.5
13-5
13.5
1 3.5
J 3.8
13.5
1 3.8
1 3.5
GAS
VOL X
CALC
14.2
14.3
14.2
14-2
14.6
14.7
14.5
14-5
14.3
14.2
14.2
14.5
14.5
14.5
14.6
14.6
14.5
14.6
15.0
15.0
15.1
15.1
15.2
15.2
15.3
14.8
14.8
14.6
S02
PPM
243.
263.
268.
263.
253.
258.
253.
253.
278.
318*
303.
283.
273.
293.
298.
278.
303.
293.
278.
273.
293.
298.
308.
308.
303.
?98.
313.
318.
REGENERATOR GAS
02 C02 502
% X X
0« 1.7
0. 2.0
0. 2.0
0. 2.3
0. 1 .9
0- 2.9
0.
0.
0.
0.
0.
0.
0.
0.
0.
0*
0.
0.
0.
0.
0.
0.
0.
0.
0.
.6
.6
.6
. 1
• 1
. 1
• 3
.3
. 1
.0
.9
. 1
• 1
.6
• 8
.2
.7
• 6
• 6
0. 2.5
0. 2.0
0. 2-2
7.4
8.2
8.2
8.2
8.6
8.6
8*6
8*6
8.6
9.2
9.2
6.8
8.4
8.2
8.2
7.0
7.2
7.0
7.2
8-2
7.8
7.6
7.6
7.4
7.4
7.4
7.4
7.8
GASIFIER
02 VOL X
ANAL CALC
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
21
20
20
2PI
.0
• 0
• 0
.0
.0
.0
.0
• 0
.0
.0
.0
• 0
.0
.0
.0
.0
.0
.0
• PI
.0
.0
.0
.0
• 0
.0
• 8
.8
.8
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20.7
20. 7
20.7
19-8
19.8
19.8
INLET
C02
ANAL
0.02
0.02
0.02
0.02
0.02
0.02
0.02
0*02
0.02
0.02
0.02
0.02
0.02
0.02
0.02
0.02
0.02
0.02
0.02
0.02
0.02
0.02
0.02
0.02
PUPI2
0.02
0.02
0.02
GAS
VOL X
CALC
0.22
0.21
0.21
0.21
0.22
0.22
0.22
0.22
0*21
0.21
0.20
0.20
0*20
0-21
0.21
0.2]
0.20
0.21
0.22
0.23
0.23
0.23
0.24
0.84
0.R7
0.85
-------
I
•fe.
13-2130
13.2230
13.2330
14.0030
14.0130
14.0230
14.0330
14.0430
14.0530
14.0630
14.0730
14.0830
14.0930
14*1030
14-1 130
14.1230
14.1330
14.1430
14*1 530
14*1630
14.1730
14.1830
14.1930
• 3
.3
.0
.0
.0
.0
.0
.0
.0
.0
.9
.9
.9
• 8
• 8
.7
.3
• 4
.3
• 3
.4
.4
• 5
14.2030 2.0
14.2130 1.9
14.2230 1.9
14.2330 2.0
15.0030 2.2
15.0130 .5
15.0230 -2
15.0330 *1
15-0430 -5
15.0530 .3
15.0630 -2
15.0730 -5
15.0830 -4
3.8
3.R
3.8
3.8
3.9
14.4
14.4
1 4.4
14.7
14.7
14.
14.
14.
14.
14.
14.
14.
14-
13.8
13-8
13.8
13.8
13.2
13.2
13.2
13.2
13.0
13.0
13.2
13.5
13.2
13.0
13.0
13.1
13. 1
13.?
14.9
1 4.9
15.
15.
15-
15.
15.
15.
15.
15.
1 4*4
14.4
14.4
14.5
14.5
14.6
14-9
14.8
14.8
14.8
14.8
14.8
14.7
14.3
1 4.4
14.4
14*3
14-2
14.7
14.9
15.0
14.7
1 4.8
14.9
1 4.7
14.8
323-
328.
328.
328.
339.
354.
328.
334.
374.
369.
344.
333.
349.
359.
359.
364.
369.
364.
364.
369.
344.
303.
339.
349.
394.
364.
369.
384.
384.
394.
399.
394.
379.
364.
349.
344.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
.6
• 6
• 6
.6
.6
• 6
.1
. 1
. 1
.9
2.3
2.2
2.2
2-8
2.8
1 .9
2.2
3.0
2.6
3.3
3.0
4.1
3.0
3.3
3-5
3-1
3.7
4.2
3.5
3-1
2.8
3-3
3-1
3. 1
3.1
3.5
8.2
8.2
8.2
8.2
7.6
7.6
8.2
8.2
8.2
8.2
8.2
7.8
7.8
7.4
7.8
7.8
7.8
7.2
7.6
7.0
6.8
6*6
7.4
7.0
7.0
7.0
7.4
6.6
7.4
6.6
6.6
6.6
6.8
6.8
6.8
7.0
20.8
20.8
20-5
20.3
20.3
20.3
20.5
20.5
17.0
17.5
18.0
18*0
18.0
17.5
17.6
17.7
17.8
17.8
17.8
17.8
17.8
17.8
17.8
17.8
17.8
17.5
17.9
17.9
17.9
18.0
18.1
18.1
18-2
18.2
18.2
18.2
19.8
19.8
19.8
19.0
19.0
19.0
19.0
19. 1
18.2
19.2
19.3
19.4
19.3
19.3
19.3
19.2
19.2
19.3
19.2
19.2
19.2
19.2
19.2
19.2
19.3
19.3
19.3
19.3
19.2
19.2
19.2
19.3
19.2
19.2
19.2
19.2
0.02 0.83
0.02 0.87
0.02 0.85
0.44 1.38
0.44 1 . 40
fl.44 1.47
0.53 L47
0.53 1.39
.96 2.07
.96
.96
• 81
• 81
2.1?
2.12
2.04
• 96
.96
.81
.88
• 96
.96
.96
.88
• 96
• 81
1 .81
1.73
.81
.73
.65
.65
.49
.49
.41
.33
• 24
. 19
.23
.24
• 26
.28
.28
• 26
• 26
.26
• 28
.28
.22
.23
• 19
. 19
.17
. 1 7
.21
.23
. 8
. 4
. 8
. 9
. 8
.33 1.22
-------
RUN 7:
GAS COMPOSITIONS
PAGE 6 OF 6
N)
I
DAY.HOUR
15.0930
15.1030
15.1130
15.1230
15.1330
15*1430
15.1530
• 1630
.1730
• 1830
.1930
.2030
.2130
.2230
.2330
15.
15-
15.
15-
15-
15-
15
15-
16
16
16
16
16
16
0030
0130
0230
0330
0430
0530
16.0630
16.0730
16*0830
16.0930
16*1030
16.1130
16.1230
F L
02
Z
• A
• 4
.4
.4
.2
.2
.4
.2
.0
.2
.3
• 4
• 3
.9
.0
.0
2.0
1 .9
1.9
2.0
2.0
2.0
?.0
2.2
2.3
2.3
2.2
2.0
U E GAS
C02 VOL X
ANAL
13.2
13.0
13*0
13.2
13«2
13*0
13.0
13.0
13*0
13-0
13*0
13.0
13.0
12.7
13.2
13.2
13-2
13-2
13.0
13.0
13.2
12.7
12-7
12.7
12.7
12.7
12.7
13.0
CALC
14.8
14.8
14.8
14.7
14.9
14.9
14.7
14.9
15-1
14.9
14.8
14.7
14.8
14*4
15.0
15.1
14.3
14.4
14*4
14.3
14.3
14.3
14.3
14.2
14. 1
14. 1
14.2
14-3
S02
PPM
354.
349.
324.
303-
334.
319.
313.
313.
344*
349.
359.
359.
354.
354.
339.
339.
333.
303.
323.
353.
343.
343.
323.
318.
313.
318.
318-
308.
REGENERATOR GAS
02
X
0.
0.
0.
0.
0.
0.
0.
0.30
0.20
0.30
0.30
0.30
0.30
0.30
0.30
0.20
0.20
0.20
0.20
0.20
0.20
0.20
0.20
0. 10
0. 10
0.20
Pi. 30
0.20
C02
X
2.8
3.6
4.6
3.9
3.0
3.4
4. 1
3*6
3-9
4.3
3-5
4.2
2-6
3-5
3.2
3.2
2.0
2.5
2.2
1.7
3.2
4.0
5.0
5.4
5.7
4.1
5.3
5.5
S02
X
7.0
7.0
7.0
7.6
7.6
7.2
6*8
6.4
6.6
6.0
6*0
5.4
6.0
6.2
6.0
6.2
7.4
7.6
7.8
8.4
7.6
7.2
7.2
7.2
7.0
7.0
7.2
6.8
GASIFIER INLET GAS
02 VOL X C02 VOL X
ANAL CALC ANAL CALC
18.0
18. 1
18.2
18.2
18.4
18.4
18.4
18.4
18.2
18.0
18-2
17.6
18.0
18.0
18.0
18. PI
18.9
20.2
20.4
20.4
20.4
20.4
20.4
20.5
20.5
20.5
2PI.5
2PI.5
18.9
19.0
18.9
18.7
18.6
18.6
18.5
18.5
18.8
18.5
18-5
18*6
18.5
18-5
18.5
18.5
19.4
19.2
19.2
19.2
19.3
19-2
19.2
19.2
19.0
19.0
18.7
18.6
.65
.57
.49
.49
• 41
.49
• 33
• 33
.49
.65
.65
• 96
.81
• 88
.81
.81
.41
0.23
0.13
0.13
0. 13
0.02
0.02
0. 1 3
0. 13
0.13
P>. 1 3
0- 13
1
-42
• 35
.36
• 58
• 58
• 59
.62
.65
.42
• 64
.62
• 60
.65
.65
• 69
• 69
. 14
.24
.25
.26
.20
.24
• 24
.24
.33
.33
.58
• 65
-------
*>.
u>
I
16.1330
6. 1430
6.1530
6.1630
6.1730
6.1830
1930
2030
2130
2230
2330
0030
7 . 0 1 30
0230
0330
0430
0530
0630
0730
0830
0930
1030
7.1130
1230
1330
1430
1530
1630
7.1730
7.1830
7.1930
7.2030
7.2130
2.0
2.0
2.0
2.0
2.0
2.0
2.0
2.1
2.1
2.0
2.0
2.0
2.0
2.0
0.
2.0
2.0
2.0
2.0
2.0
2.0
2.0
1 .6
1.8
1 .8
1 .6
2.0
2.4
2.0
1 .6
2.0
2.0
2.P5
1 3.0
13.0
13.0
1 3-0
13.0
12.7
12.7
12.7
12.7
12.7
12.7
12-7
13.0
13.0
9.4
13.2
13-2
13.2
13.2
13.2
13-0
13-0
13.2
13-2
13.0
13.0
13.0
13.0
13.2
13-2
13.0
4.3
4.3
4.3
4.3
4.3
4.3
4.3
4.2
4.2
4.3
4.3
4.3
4.3
4.3
5.8
4.3
4.3
4.3
4.3
4.3
4.3
4.3
4.6
4.5
4.5
4.6
4.3
4*0
4.3
4.6
4.3
13.0 14.3
13-P) 14.3
318.
323.
323.
328.
328.
318.
313.
333.
343-
389.
414.
419-
424.
434.
420.
414*
404*
394.
384.
379.
369.
379.
404.
399.
399.
404.
404.
358.
353-
364.
353.
353-
353.
0.20
0. 10
0. 10
0. 10
0.10
0. 10
0. 10
0. 10
0.10
0. 10
0. 10
0.10
0.10
0.10
0. 10
0.10
0.10
0.10
0. 10
0.10
0.10
0.10
0. 10
0. 10
0.10
0.10
0.10
0. 10
0.20
0.20
0. 10
0. 10
0. 10
5.2
5.1
5.0
4. 7
5.4
5.2
5.5
4.7
3.5
2.5
2.0
1.7
2.2
1 .8
3.1
2.8
3-3
4. 1
4.3
4.9
5.0
5.3
6.0
4.5
5.4
4.7
5.1
4.5
4.6
4. 1
3.7
4.5
3.6
7.2
7.4
7.4
7.4
7.2
7.6
7.2
7.4
7.6
7.6
7.8
7.8
7.4
7.4
8.2
7.0
7-0
7.0
7.4
6*6
7.4
7.4
7.2
7.4
7.4
7.4
7-2
6.8
7.0
7.6
7.4
7.0
6.8
20.6
20.6
20.2
20.2
20.2
20.4
20.4
20.2
20.2
20.2
20.2
20.2
19.0
19.0
19.0
19.0
19.0
19.0
19.0
19.0
20.2
20-1
20. 1
20.5
20.5
20.5
21 .0
21 .0
21 .0
21 .0
21 .0
21 .0
21 .1
19. PI
18.6
19. 1
18.9
19.0
19.0
19.0
18.6
18.5
18.5
18.5
18.5
18.6
18.6
18.3
18.6
18«6
18.6
18.6
18*6
18.5
18.6
18-5
18-9
18.5
18.5
20.6
20.6
20.6
20.6
20.6
20.6
20.6
0. 1 3
0.02
0.53
0.53
0.44
0.34
0.34
0.53
0.53
0.53
0.53
0-53
1. 16
1.16
0.99
0.99
0.99
0.99
0.99
0.99
0.53
0.63
0.63
0. 44
0.44
0.23
.39
.65
.30
.40
.35
.34
• 33
• 63
.65
• 65
.65
.65
.66
.66
• 19
• 6F
• 68
• 68
• 68
• 68
• 68
• 65
• 69
• 43
• 69
• 69
0.02 0.25
0.02 0.?6
0.02 0.26
0.02 0.26
0.02 0.26
0.02 0-26
0.0? 0.?6
-------
RUN 7:
APPENDIX D: TABLE VI.
SULPHUR AND STONE CUMULATIVE BALANCE-
PAGE 1 OF 6
I
*fc
DAY. HOUR
• 1230
. 1330
.1430
• 1530
• 1630
- 1730
• 1830
• 1930
• 2030
• 2130
• 2230
• 2330
2*0030
2.0130
2.0230
2*0330
2.0430
2.0530
2.0630
2.0730
2.0830
2-0930
2.1030
2-1130
2-1230
2.1330
2.1430
2.1530
TOTAL
K I L
IN FLUE
0.141 0.110
0.282 0.222
0.413 0.280
0.557 0.376
0.695 0.443
0*833 0.515
0.971 0*588
•109 0.657
.247 0.725
•385 0*792
•522 0.856
•660 0*923
.798 0*994
• 936
2.073
2.210
2.348
2-485
2-622
2.759
2*896
3-033
3*170
3*306
3*443
3*579
3*717
*058
• 115
• 172
• 225
.277
• 324
• 369
.412
.454
.490
• 526
.561
• 591
• 624
3*854 1,660
S U L
0 M 0
REGEN
0.035
0*039
0*059
0.093
0*132
0*188
0*242
0.306
0*366
0*421
0*508
0*573
0.662
0.734
0*809
0*881
0*954
1 .045
I .142
1 .209
1 .272
1 -356
• 438
.529
.624
.724
• 818
.906
P H U
L S
FINES
0.005
0.010
0.015
0*020
0*025
0*029
0*034
0.036
0.038
0*039
0.040
0*071
0.072
0*073
0.102
0. 105
0.107
0.136
0.167
0. 176
0.205
0.210
0.214
0.219
0.22?
0.250
0.253
0.255
R
IN-OUT
-0.009
0*01 1
0*065
0*069
0.095
0. 01
0. 08
0. 10
0. 18
0. 33
0. 18
0.093
0.069
0*070
0.048
0.052
0.061
0.027
-0.01 1
0.005
0.007
0.013
0.027
0.032
0.035
0.014
0.022
0.033
EQUIVALENT BURNT
K I
FEED
0.
0.
0.
1.3
9*8
19.0
24.4
30.6
36.7
42*6
48*3
54*2
61 *6
69*8
77*0
85.7
95.5
106.0
1 16.8
127.6
133-1
147.9
1 59.2
169.7
181 .5
19P.0
198.2
205.6
L 0 G R A M
REMOVED I
2.0
4.0
6.0
7.9
9.9
12.0
14.0
15.3
15.9
16*5
17.1
34.1
34.7
35.3
53.4
54.8
56.2
76. 1
98.0
103*6
126.0
129.3
132.7
136. 1
138.9
167.6
170.0
172.3
STONE
S
N-OUT
-2*0
-4*0
-6*0
-6*7
-0*2
7.0
10.4
15.3
20.8
26*2
31-2
20.1
26*?
34-5
23.6
31.0
39.3
29.9
18.8
24.0
12.2
18.6
26.5
33.6
42.6
24.4
28.2
33.4
-------
Ul
2. 1630
2. 1730
2 . 1 8 30
2.1930
2.2030
2.2130
2.2230
2.2330
3*0030
3-0130
3.0230
3.0330
3.0430
3.0530
3.0630
3.0730
3.0830
3.0930
3.1030
3 . 1 1 30
3.1230
3.1330
3.1430
3.1530
3. 1630
3.1730
3.1830
3.1930
3.2030
3-2130
3-2230
3.2330
4.0030
4*01 30
4.0230
4.0330
3.991
4. 131
4.267
4.404
4.541
4.679
4.817
4.955
5.092
5.228
5.367
5.505
5.643
5.780
5-917
6.055
6-193
6.330
6.468
6.605
6.743
6*880
7.019
7. 155
7.292
7.429
7.566
7.704
7.841
7.978
8. 1 15
8.253
8.394
8.538
8.682
8.829
1 .702
1 .748
.793
.841
• 887
.930
.971
2.008
2.045
2.086
2. 124
2. 160
2. 194
2.227
2-260
2.294
2.329
2.365
2.398
2.432
2.466
2.497
2.526
2.555
2.583
2.611
2.638
2.664
2.689
2.714
2.739
2.764
2.788
2.815
2.844
2.874
2.014
2.1 17
2-193
2.290
2.378
2.470
2.569
2.671
2.771
2.885
2-975
3.071
3.173
3-274
3.368
3.469
3.573
3.674
3.775
3-868
3.975
4.074
4. 185
4.300
4.403
4-505
4.615
4.71 1
4.805
4-889
5.013
5. 133
5.255
5.366
5.490
5.621
0.258
0.272
0.274
0.276
0.279
0.280
0.282
0.284
0.286
0.288
0.290
0.291
0.293
0.295
0.297
0.299
0.305
0.312
0.319
0.325
0.331
0.337
0.343
0.350
0.357
0.366
0.374
0.383
0.393
0.403
0.412
0.419
0.427
0.432
0.438
0.447
0.017
-0.006
0.006
-0.003
-0.003
-0.002
-0.005
-0.009
-0.010
-0.030
-0.022
-0.018
-0.017
-0.016
-0.007
-0.006
-0.014
-0.020
-0.025
-0.020
-0.029
-0.028
-0.036
-0.050
-0.052
-0.052
-0.060
-0.055
-0.046
-0.028
- 0 . 0 49
-0.063
-0.076
-0.075
-0.089
-0. 1 13
21 3.9
221 .8
228.5
235.9
243.6
251.9
259.8
268.0
276.5
285.5
293.4
301 .9
310.4
318.1
330.2
343.5
358. 1
371.7
384-3
398.2
416*4
434. 1
450.6
468.0
486.0
506.3
521.7
539. 1
555.3
571 .5
580.7
587.4
593.6
600. 5
607.9
614.4
174.6
191 .2
193.4
195.6
197.5
199.2
200.9
202.5
204.2
205.9
207.5
209.2
210.9
212.5
214.2
215.9
222.0
229.5
236.6
242.9
248.9
254.8
260.8
266.8
274.2
282.2
290.3
299.0
308.6
318-2
326.6
333.7
340.8
346. 1
351 .5
360.5
39.3
30.6
35. 1
40.3
46. 1
52.6
58.9
65.5
72.3
79.6
85.9
92.7
99.5
05.6
16.0
27.7
36.2
42.2
47.8
55.3
67.5
79.3
89.8
201.3
211.7
224.0
23L4
240. 1
246.7
253.3
254.2
253.8
252.8
254.4
256.4
253.9
-------
RUN 7:
APPENDIX Dl TABLE VI•
SULPHUR AND STONE CUMULATIVE BALANCE.
PAGE 2 OF 6
I
*>.
I
DAY. HOUR
4*0430
4.0530
4.0630
4.0730
4.0830
4.0930
4.1030
4.1130
4.1230
4.1330
4. 1430
4.1530
4. 1630
4.1730
4.1830
4* 1930
4.2030
4*2130
4.2230
4.2330
5*0030
5*0130
5.0230
5.0330
5.0430
5.0530
5.0630
5.0730
T 0
K
IN
8-974
9*120
9*267
9.412
9*559
9*704
9*850
9*996
10*139
10.283
10.426
10.570
10.713
10.857
1 .001
1 *144
1 .288
1 .432
1 .576
1 .720
1 .864
12.008
12-152
12*296
12.440
1 2 • 58 5
12*73?
12.880
T A L
I L
FLUE
2.906
2.941
2.973
3.002
3*031
3.061
3.092
3.125
3.160
3*195
3*229
3.262
3.294
3.328
3*361
3.393
3.423
3.450
3.477
3.503
3.525
3.551
3-581
3*610
3.639
3.667
3.695
3.724
S U L
0 M 0
REGEN
5.740
5.842
5.943
6.050
6.160
6.271
6*381
6.494
6.599
6*707
6-809
6.921
7.037
7*145
7*245
7*356
7.470
7.585
7.694
7.813
7.926
8.030
8. 1 52
8.266
8.375
8.489
8.605
8.725
P H U
L S
FINES
0.452
0.460
0.465
0.469
0.472
0.474
0.477
0*480
0.484
0.489
0.494
0.499
0.503
0.508
0.512
0.516
0.519
0.523
0.526
0.532
0.537
0.541
0.546
0.550
0.554
Pi. 558
0.563
0.568
R
IN-OUT
-0. 124
-0. 124
-0.1 15
-0.108
-0.104
-0.102
-0. 100
-0.103
-0. 104
-0.108
-0.105
-0.1 12
-0.122
-0.124
-0.1 18
-0. 120
-0. 123
-0.126
-0. 121
- PI . 1 29
-0. 124
-0.1 14
-0. 127
-0. 130
-0. 129
-P. 130
-0.131
-0. 1 41
EQUIVALENT BURNT STONE
K I
FEED
621.3
627.7
633.4
639.8
647.7
654.2
659.3
665.7
672. 1
678.5
685-5
691.6
697-3
704.7
712-9
720.4
726-8
733.5
740.9
747.9
754.8
761.7
769.9
778.2
786.1
794.6
802.8
809.7
L 0 G R A
REMOVED
365.5
372.6
377.6
381.5
384.0
386.4
388.8
391.2
395.7
400.2
404.7
409.2
413*8
418.3
421.9
425.2
428.6
431.9
435.2
440.4
444.6
448.8
452.9
457.0
461 . 1
465.2
470.2
475.3
M S
IN-OUT
255-8
255*1
255*7
258-3
263*8
267.8
278.5
27-W5
276.4
278.3
280*8
282*4
283.5
286*5
291*1
295*2
298.3
301*6
305*7
307.4
310*2
313.0
317.0
321*2
325.0
329*4
332*6
33** 5
-------
5.0830
5.0930
5.
5.
5.
5.
5-
5.
5.
5.
5.
5
5.
5.
5.
5.
6.
6.
6.
6.
6.
6.
6*
6.
6*
6.
6-
6.
6.
6.
6.
1030
1130
1230
1330
1430
1530
1630
1730
1830
.1930
2030
2130
2230
2330
0030
0130
0230
0330
0430
0530
0630
0730
0830
0930
1030
1130
1230
1330
1430
6. 1530
6.
6.
1630
1730
6*1830
6«
1930
13.028
13.177
13-325
13.473
13.621
13.769
13.917
14.065
14.212
14.360
14.508
14.656
14.803
14.951
15.099
15.246
1 5 . 39 4
15-542
15.691
15.840
15.989
1 6 • 1 38
16.288
16-437
16.586
16.736
16.885
17.034
17.184
17.334
17.483
17.633
17.782
17.932
18.081
18.231
3.754
3-785
3-815
3.845
3.876
3.907
3-938
3-969
4.000
4.031
4.061
4.092
4.125
4.157
4.189
4.226
4.263
4.302
4.341
4*380
4*418
4.456
4.494
4.533
4.573
4.611
4.648
4.685
4.725
4.768
4.81 1
4-855
4.900
4.948
5.009
5.057
8.846
8.
9.
9.
9.
9.
9.
9.
9.
9.
10.
10
10.
10.
10*
10.
10.
10.
10*
1 •
1 •
1 •
1 •
1 .
1 •
1 .
1 •
11 .
12.
12.
12.
12.
12.
12.
12.
964
087
205
330
450
569
689
805
924
037
.164
271
390
540
641
786
886
993
093
195
287
376
471
573
681
799
917
031
142
252
367
488
602
729
12.836
0.573
0.591
0.596
0.600
0.605
0.609
0.613
0.618
0.622
0.627
0.631
0.636
0.641
0.646
0.651
0.656
0.659
0.663
0.667
0.671
0.682
0.688
0.694
0.698
0.703
0.707
0.712
0.722
0.726
0.730
0.734
0.744
0.747
0.751
0.754
0.764
-0.
-0.
-0.
-0.
-0.
-0.
-0.
-0.
-0.
-0.
-0.
-0
-0.
-0.
-0.
-0.
-0.
-0.
-0.
-0.
-0.
-0.
-0.
-0.
-0.
-0.
-0.
-0.
-0.
-0.
-0.
-0.
-0.
-0.
-0.
-0.
145
163
173
178
190
196
203
21 1
215
222
222
.237
233
242
281
277
315
309
310
304
307
294
276
266
262
263
274
289
297
307
314
333
353
369
41 1
426
818.2
825. 1
831.0
838.0
844.7
851.8
859.0
866-5
874.2
880-9
885.7
890.1
893-9
897.0
900.9
904.7
908.6
912.7
917.3
92L4
925.8
930.4
934.3
938.6
944. 5
950.7
955-8
959.7
962.5
966. 1
970.2
974.6
978.7
984.6
989.4
993-3
480.2
501 .4
506.3
51 1.2
515.8
520.3
524.8
529.2
533.9
538-6
543.4
548.2
553. 1
558-2
563.2
568.2
572. 1
576.0
579.9
583.9
593.8
599.7
605.7
609.4
613. 1
616.8
620.5
628.2
631.9
635.5
638.9
646.4
649.6
652.6
655.6
662.5
338-0
323.8
324.8
326.8
328.9
331 .6
334.3
337.2
340.3
342.2
342.3
341.9
340.8
338.9
337.7
336.5
336.4
336.6
337.4
337.6
332.0
330.7
328.6
329.2
331 .4
333.9
335.3
331 .5
330.6
330.6
331 .2
328-2
329. P
332. &
333.8
330.8
-------
RUN 7:
APPENDIX D: TABLE VI.
SULPHUR AND STONE CUMULATIVE BALANCE.
PAGE 3 OF 6
CO
DAY
6*
6*
6*
6.
7.
7.
7.
7.
7.
7.
7.
• HOUR
2030
2130
2230
2330
0030
0130
0230
0330
0430
0530
0630
TOTAL
K I L
18
18
18
18
18
19
19
19
19
19
19
IN
• 381
• 530
.679
• 829
.979
• 127
• 279
• 429
• 578
• 728
• 877
FLUE
5*102
5* 148
5. 195
5*244
5.294
5.343
5.393
5-443
5.493
5.546
5.600
0
1
1
1
1
1
1
1
1
1
1
1
S U L
M 0
RE GEN
2-936
3.037
3.156
3.254
3.362
3.468
3-583
3*685
3.792
3.899
3.991
P H U
L S
FINES
0-767
0.772
0.778
0.789
0.794
0.800
0*810
0.814
0.817
0.821
0.824
R
IN-OUT
-0.424
-0.427
-0.449
-0.457
-0.472
-0.483
-0.507
-0*513
-0.524
-0.538
-0.538
EQUIVALENT BURNT STONE
KILOGRAMS
FEED
998.2
1002.3
1007.2
1011.5
1014.9
1020.0
1025.1
1030.3
1034.1
1038.2
1040.0
REMOVED
665*5
669.7
674.2
682.7
687.2
691.7
699.5
702.6
705.7
708.8
711.8
IN-OUT
332-7
332-6
333.0
328.9
327.7
328.3
325.7
327.7
328.5
329.5
328.2
STONE CHANGE
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
7.
0730
0830
0930
1030
1 130
1230
1330
1430
1530
1630
1730
1830
1930
2030
2130
2230
20
20
20
20
20
20
20
21
21
21
21
21
21
21
22
22
.027
• 178
• 328
• 478
• 622
• 772
.922
.073
.223
• 371
.522
• 673
.822
.973
.122
.272
5-656
5.710
5.762
5.812
5.860
5.911
5-960
6.010
6.061
6.1 1 I
6.162
6.212
6.261
6.308
6.353
6.401
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
1
4*084
4*181
4.279
4.383
4.482
4.583
4*688
4.784
4.885
4.981
5-078
5. 185
5.279
5.380
5-485
5.590
0.827
0.835
0*838
0*841
0.844
0.847
0.849
0.852
0.861
0.863
0*868
0*875
0.?88
0-894
0.904
0.919
-0.540
-0.549
-0.551
-0. 558
-0.564
-0.568
-0.575
-0.574
-0.583
-0.584
-0.586
-0. 600
-0.605
-0.610
-0.620
-0.638
1 0 48 • 8
1059.0
1066.7
1073.4
1080.6
1088.3
1095.7
102.4
1 10.4
1 18-8
127.1
133.2
139.4
146.6
152-7
158. 1
714.4
720.3
722.8
725.2
727.7
730.1
732.6
735.1
741 .0
743.5
747. 7
753.8
763.3
769.4
778.5
793.5
334.3
338-7
343.9
348.2
352.9
358. 1
363- 1
367.3
369.4
375.4
379.3
379.4
376.0
377. P
37/i. 3
36^- 7
-------
7.2330
8*0030
8.0130
8-0230
8*0330
8.0430
8.0530
8*0630
8.0730
8.0830
22.421
22.571
22.720
22.870
23.020
23.169
23.319
23.468
23.618
23-768
6.448
6.494
6.543
6.592
6.640
6.687
6.735
6-784
6.833
6.879
15.688
15.785
15-884
15.983
16.084
16. 182
16.274
16-375
16.471
16.566
0.931
0.938
0.946
0.954
0.961
0.971
0.981
0.994
1 .001
1 .010
-0.645
-0.647 1
-0.652
-0.658
-0.665
-0.671
-0.671
-0.684
-0.686
-0.688
1 162.5
1167.9
173.8
179.9
186.6
193.3
201.0
213-6
228.5
1244.6
804. 4
811-1
817.9
824.7
831 .5
839.9
848. 1
857.9
864.2
873.8
358. 1
356.7
355.9
355.2
355.1
353.4
352.9
355.7
364.2
370.8
SHUT DOWN AT 8.0830 FOR 21 HOURS
9.
9.
9.
9.
9.
9.
0530
0630
0730
0830
0930
1030
23.
24.
24.
24.
24.
24.
903
047
187
324
461
598
6.944
7.011
7.075
7.133
7. 190
7.243
16.570
16-645
16.719
16.814
16.884
16.953
1 .023
1.035
1.048
1.063
1.067
1.070
-0.633
-0.644
-0.655
-0.686
-0.680
-0.668
1 2 59 • 8
1277.0
1 29 1 . 4
1305.7
1319.1
1336*6
886*
899.
913.
929.
932.
936.
7
5
2
5
8
0
373. 1
377.5
378.2
376.2
386.3
400.5
STONE CHANGE
9.
9-
9-
9.
9.
9.
9-
9.
9.
9.
9.
9.
9.
10.
10*
1130
1230
1330
1430
1530
1630
1730
1830
1930
2030
2130
2230
2330
0030
0130
24.
24.
25.
25.
25.
25.
25.
25.
25.
26.
26.
26.
26.
26.
26.
737
879
022
166
309
453
596
748
896
044
192
340
488
636
784
7.293
7.343
7.389
7.430
7.471
7.512
7.552
7.597
7.639
7.681
7.722
7.765
7.309
7.851
7.896
17.031
17.105
17.186
17.274
17.353
17.460
17.569
17.662
17.756
17.850
17.944
18.043
18. 141
18.239
18.339
1.074
1 .078
1.086
1.094
1.102
1 .110
1.117
1 .122
1 . 132
1-141
1.150
1.159
1 .169
1 . 1 79
1.189
-0-661
-0.647
-0.638
-0.632
-0.616
-0.629
-0.642
-0.634
-0.631
-0.628
-0.624
-0.626
-0.630
-0.633
-0.640
1353.0
1379.4
1410.0
1438.5
1467.5
1489.8
1497.8
1 509 . 3
1 520.4
1 532.7
1545.5
1557.3
1569.4
1 579.9
1 59 1 . 2
939.
942.
950.
958.
967.
976.
983.
988.
995.
1004.
1012.
1021 .
1029.
1039.
1048.
3
5
7
9
*,
M
1
0
2
9
0
5
0
9
3
7
413.7
436.9
459.3
479.6
500. 1
513.7
514.7
521. 1
524. 4
528.7
533.0
536.4
539.5
540.7
542.6
-------
RUN 7:
APPENDIX D: TABLE VI.
SULPHUR AND STONE CUMULATIVE BALANCE.
PAGE 4 OF 6
tn
O
DAY. HOUR
10.0230
10.0330
10.0430
10.0530
10.0630
10.0730
10.0830
10.0930
10.1030
10.1 130
10. 1230
10.1330
10.1430
10.1530
10. 1630
10. 1730
1 0 • 1 8 30
1 0 • 1 9 30
10.2030
1 0 • 2 1 30
10.2230
10.2330
1 .0030
1 . 0 1 30
1 .0230
1 .0330
1 .0430
1 .0530
TOTAL
K I L
IN
26.932
27.080
27.229
27.377
27.526
27.674
27.822
27.970
28-119
28.266
28 • 4 1 6
28.564
28 . 7 1 3
28.861
29 . 009
29 . 1 58
29.306
29.454
29.603
29.751
29.899
30.048
30-196
30.344
30.492
30.640
30.788
30-936
FLUE
7.941
7.987
8.032
8.078
8.123
8.166
8.209
8.254
8.297
8.334
8.369
8.405
8.442
8.474
8.505
8.535
8.563
8.589
8.616
8-644
8.672
8.702
8.734
8-767
8.800
8.833
8.866
8.898
S U L P H U
0 M 0 L S
REGEN FINES
18.437 1.200
18.541 1.210
18.638
18.733
18.832
18.928
19.022
19.109
19.207
19.304
19.404
19.500
19.580
19.674
19.765
19.861
19.976
20.091
20.205
.221
.232
.240
• 248
.256
• 264
• 286
• 296
• 307
.324
• 339
.372
• 384
• 397
.413
.428
.439
20.322 1.450
20.436 1.460
20.550 .484
20.659 .495
20.778 -505
20.874 -515
20.963 .525
21-058 .536
21-176 .546
R
IN-OUT
-0.646
-0.658
-0.662
-0.665
-0.669
-0.668
-0.665
-0.656
-0.671
-0.669
-0.664
-0.665
-0.649
-0.659
-0.644
-0.636
-0.647
-0.654
-0.658
-0.664
-0.669
-0.689
-0.692
-0.707
-0.697
-0.681
-0.672
-0.683
EQUIVALENT BURNT STONE
KILOGRAMS
FEED
1604*3
1616.6
1629.2
1641.8
1654. 1
1667.2
1680.6
1698.3
1726.8
1754.5
1782.8
1812.0
1841.0
1868.5
1897.3
1928.3
1945.0
1956.3
1968.4
1979.9
1992.8
2005.3
2016.4
2027.4
2038.5
2050.8
2063-6
2077. P)
REMOVED
1058.0
1068.0
1078.2
1088.4
1096.2
1 103.2
1 110.7
1 118.7
1 143.0
1 152.3
1161.7
1 177.6
1 192.0
1213.6
1223.2
1235.0
1249. 1
1261 .4
1271 .3
1279.6
1287.9
1308.6
1317.0
1325.3
1333.4
1341 .3
1349.3
1356.9
IN-OUT
546-3
548.6
551.0
553.4
557.9
564.0
569.8
579.6
583.8
602.2
621* 1
634.4
649.0
654.9
674-0
693-3
695.9
694.9
697. 1
700.3
704.8
696.7
699.4
702. 1
705.0
709.4
714.4
720. 1
-------
Ol
1
1
1
1
1
1
1
1
]
1
1
1
1
1
1
1
1
1
.0630
.0730
.0830
.0930
• 1030
• 1 130
.1230
• 1330
.1430
• 1530
.1630
• 1730
. 1830
.1930
.2030
.2130
• 2230
-2330
12.0030
12.0130
12.0230
12.0330
12.0430
12.0530
12.0630
12-0730
12.0830
12.0930
12.1030
12-1 130
12.1230
12.1330
12-1430
12-1530
12.1630
31 .084
31 .232
31 *381
31.529
31.677
31.825
31 .972
32.120
32.268
32.416
32.564
32.712
32.859
33.007
33. 154
33*301
33.448
33-595
33.739
33-879
34.018
34. 157
34.297
34-437
34.576
34.716
34.854
34.992
35. 130
35.267
35.404
35.541
35.679
35.816
35.953
8.929
8.960
8.991
9.021
9.053
9.085
9.115
9. 147
9.178
9.209
9.240
9.270
9.301
9.332
9.361
9.393
9.427
9.466
9.505
9.536
9.565
9-594
9.622
9.648
9.674
9.700
9.723
9.747
9.771
9.794
9.817
9.839
9.859
9.880
9-902
21 .283
21.388
21 .497
21.607
21 .723
21 .827
21 .944
22.066
22* 181
22.296
22.425
22.562
22*662
22.786
22*915
23.026
23. 129
23.236
STONE CHA
23-340
23*439
23.459
23-556
23.662
23.773
23.876
23.982
24.078
24. 178
• 573
.583
.592
• 600
.613
.622
.632
.641
.650
• 660
• 674
• 683
.693
.704
.716
.728
• 813
• 835
JGE
.860
• 880
.901
.921
.941
.961
.967
.973
.979
• 986
24.275 1*993
24-385 1.999
24.497 2.007
24.601 2.016
24.703 2.025
24.813 2.033
24.925 2.046
-0.701
-0.697
-0.699
-0.700
-0.712
-0.709
-0.719
-0.733
-0.741
-0.749
-0.776
-0.804
-0.796
-0*815
-0.839
-0*845
-0.921
-0*943
-0*965
-0.976
-0*906
-0.914
-0.928
-0.946
-0.941
-0.939
-0.926
-0^918
-0.909
-0.912
-0.9 17
-0.915
-0.908
-0.9 10
-0.920
2089.8
2102.6
21 15.5
2128.8
2142.2
2154-8
2 1 68 . 1
2182.5
2195- 1
2205-3
2215.6
2226.4
2239.7
2252.3
2264*6
2276*7
2283*6
2284*2
2299*8
2317*8
2337*2
2358*0
2381*7
2405.9
2428.0
2450.4
2476.0
2499.4
2521.3
2537.7
2556.8
2576.8
2595-9
2618.3
2640.9
1373.7
1 38 1 . 1
1388. 1
1394.9
1406*3
1413*5
1420*6
1427.8
1435*0
1442*2
1453*8
1460*9
1 468 . 1
1476*6
1485.6
1494*6
1568*1
1592* 1
1619*6
1642*7
1665*8
1689.9
1713.5
1738.0
1742.8
1747.9
1753*3
1759*4
1765.5
1771 .6
1778-3
1786.4
1794.5
1802.6
1814.4
716.1
721.6
727.3
733.9
735.9
741.3
747.5
754.7
760* 1
763*2
761*8
765.5
771 .&
775.7
779.0
782* 1
715*6
692* 1
680*2
675-1
671-4
668. 1
668.2
668.0
685.2
702.5
722.7
740-0
755-8
766- 1
77P.5
790.4
801 • 4
815.7
826. 5
-------
RUN 7:
UI
to
APPENDIX D: TABLE VI.
SULPHUR AND STONE CUMULATIVE BALANCE
PAGE 5 OF 6
T
DAY. HOUR
12-1730
12*1830
12*1930
12*2030
1 2 * 2 1 30
12.2230
12*2330
13*0030
13.0130
13*0230
13*0330
13.0430
13-0530
13*0630
13*0730
13*0830
1 3 . 09 30
13* 1030
1 3 • 1 1 30
13* 1230
13* 1330
13* 1430
13.1 530
13- 1630
13. 1730
1 3. 1830
13- 1930
13.2030
IN
36.091
36*229
36*367
36.504
36*645
36.781
36*925
37.063
37*200
37*337
37.475
37.612
37.750
37.888
38.027
38. 166
38.303
38 . 439
38.576
38 . 7 1 2
38.848
38.983
39 * 1 J 9
39*254
39*387
39*525
39.662
39.798
0 T A L
K I L
FLUE
9.924
9.948
9.973
9*997
10*020
10*043
10.067
10*090
10.1 15
10. 145
10. 173
10. 198
10.223
10.250
10.277
10.302
10.329
10.355
10-380
10.403
10.429
10.455
10.481
10.508
10.533
10.560
10.587
10.616
SULPHUR
0 M 0 L S
REGEN
25-019
25.121
25.210
25.308
25.411
25.514
25.613
25.713
25.814
25.916
26.029
26*1 19
26.224
26*326
26*422
26*504
26-597
26-683
26.783
26.890
26.993
27.096
27.194
27.289
27.381
27.473
27.559
27.661
FINES
2.059
2.072
2*087
2*105
2*123
2*138
2- 145
2-153
2*160
2*168
2*175
2*183
2. 190
2* 198
2.206
2.213
2.238
2.280
2.32!
2.341
2-353
2.365
2.374
2.383
2-391
2.405
2.419
2*4?B
IN-OUT
-0.911
-0*912
-0.903
-0*905
-0*909
-0*913
-0.900
-0.893
-0.890
-0.890
-0.902
-0.887
-0.887
-0*886
-0.878
-0.853
-0.862
-0.880
-0.907
-0.923
-0.927
-0.932
-0.930
-0.925
-0.918
-0.912
-PI. 904
-PI. 906
EQUIVALENT BURNT STONE
KILOGRAM*;
FEED
2667.6
2695.0
2720.4
2741.7
2763.5
2790.4
2814*9
2834*9
2855*6
2878*0
2893*9
29 1 1 . 7
2928*6
2951.8
2970.1
2994. 1
3013.0
3032. 1
3043. 1
3052.0
3058.0
3065.0
3072-0
3080. 1
3090.0
3100. R
3112-4
31?0.7
REMOVED IN-OUT
1826.2
1838.0
1852.2
1868.9
1885.6
1900.2
1908.1
1916.0
1924.0
1931 .9
1939.7
1947.5
1955-3
1963- 1
1970.8
1978-4
2000-7
2037.4
2074.2
2096.4
2107-9
2119.5
2 1 28 • 1
2136.7
21 45-3
2 1 59 . 6
21 74-6
2183-S
841.4
857.0
868* 1
872.7
877.8
890*3
906.9
918*8
931.7
946. 1
954.2
964- 1
973.3
988.8
999.4
1015.7
1012.3
994. 7
969.0
955.7
f ••* m^ " t
9 50 • 0
f *J TtJ • « J
945*4
943. 8
9 43* 3
9 44, 7
941.?
9 T 7. »
s O ' • ~
937. P
-------
U)
i
13.3130
13.2230
13.2330
1 4*0030
14.0130
14.0230
14.0330
1 4.0430
14.0530
14.0630
14.0730
14.0830
14.0930
14. 1030
14. 1130
14. 1230
14.1330
14. 1430
14-1530
14*1630
14.1730
14. 1830
14. 1930
14*2030
14-2130
14.2230
14.2J30
15.0030
15.0130
15.0230
15.0330
15.0430
15.0530
15.0630
1 5.0730
15.0830
39.
40.
40.
40*
40.
40*
40.
40.
41 •
41 .
41 •
41 .
41.
41.
41 •
41 •
42.
42.
42.
42.
42.
42*
42.
43*
43.
43.
43.
43.
43.
43.
44.
44.
44.
44.
44.
44.
935 1
072
209 1
346
483
619
756
892
029
167
304
441
578
715
852
990
127
264
401
538
675
813
950
087
226
364
500
636
774
912
050
187 1
324 1
462 1
599 1
736
10.645
10.674
10.702
10.731
10.760
0.791
0.820
0.849
0.882
0.914
0.945
0.976
1.008
1 .041
1.073
1 .106
1 .139
1-171
1-204
1.237
1 -267
1*294
1.325
1*357
1.393
1*427
1 .460
1 .496
1 .530
1.565
1 .601
1.636
1 . 670
11 .702
I 1 .733
H . 764
27
27
27
28
28
28
28
28
28
28
28
28
28
29
29
29
29
29
29
29
29
29
29
29
30
30
30
30
30
30
30
30
30
30
31
31
.765
• 869
.975
.074
• 166
.256
• 353
.461
.554
.657
.759
• 855
• 954
.049
• 151
• 249
• 349
.440
• 536
• 623
.711
.797
• 895
.992
.087
• 182
.282
• 382
.496
.592
.679
. 764
.846
.928
.010
.094
2.433
2.438
2.443
2.449
2.457
2.465
2.473
2.481
2-489
2*497
2.506
2.514
2-522
2.530
2.538
2.546
2-554
2.563
2.571
2*579
2.585
2*589
2.592
2.596
2.599
2.603
2.625
2.642
2.653
2.664
2.675
2.687
2.7P0
2.714
2.729
2.744
-0.907
-0.909
-0.912
-0.908
-0.900
-0.892
-0.890
-0.898
-0.896
-0.902
-0.906
-0*905
-0.906
-0.905
-0.910
-0.912
-0.9 16
-0.910
-0.910
-0.900
-0.887
-0.867
-0.862
-0.857
-0.854
- 0 . 8 48
-0.867
-0.884
-0.906
-0.909
-0.905
-0.900
-0.891
-0.882
-0.873
-0.R65
3129
3138
3146
3154
3162
3170
3178
3185
3193
3202
3209
3217
3224
3232
3239
3246
3254
3261
3269
3276
3285
3297
3306
3314
3322
3331
3338
3344
3352
3362
3371
3381
3391
3400
3409
3421
• 1
• 8
.9
.2
.5
.9
.4
.7
.5
. 1
. 7
.2
.5
.3
.8
.8
• 4
.9
.2
.7
.9
.8
.7
.2
.8
.7
• 2
.9
. 7
.7
.6
.0
• 3
.7
.3
.4
2188.3
2193.0
2197.8
2203.5
221 1 .0
2218.5
2226-2
2233.8
2241 .5
2249.4
2257.3
2265.2
2272.9
2280.2
2287.4
2294.7
2302-2
2309.7
2317.0
2324*2
2329.6
2333*0
2336*0
2339.1
2342.2
2345.2
2361.8
2374.9
2382.4
2389.8
2397.3
2404. B
2413.2
2421-9
2430.6
2439.4
940.8
945.8
949. 1
950*7
951.5
952.3
952-2
951 .9
952.0
952.7
952.4
952.0
951 .6
952*1
952.4
952.2
952. 1
952.2
952.3
952.5
956.3
964-8
970*6
975.1
980.7
986.5
976.4
970.0
970.4
972.9
974.3
976.?
978.?
978.P
978.7
9«2. P
-------
RUN 7:
APPENDIX D: TABLE VI.
SULPHUR AND STONE CUMULATIVE BALANCE
PAGE 6 OF 6
T
DAY* HOUR
15.0930
15-1030
1 5- 1 130
1 5. 1230
15. 1330
15. 1430
15.1530
15.1630
15.1730
15-1830
15.1930
15*2030
15-2130
15.2230
15.2330
16.0030
16*0130
16*0230
16*0330
1 6*0430
16*0530
16*0630
16*0730
16-0830
16.0930
16. 1030
16. 1 130
16. 1230
IN
44*874
45.012
45. 149
45.287
45.424
45*561
45.698
45.835
45.973
46. 1 10
46-248
46.385
46.523
46.659
46*796
46*933
47.069
47.205
47.342
47. 478
47.614
47.751
47.888
48.024
48 • 1 60
48 • 29 7
48.433
48.57?)
0 T A L
K I L
FLUE
1 .795
1 -826
1 .855
1 -882
1 -912
1 .940
1 .967
1 .995
12*025
12*056
12*087
12* 1 19
12.151
12*183
12.212
12.242
12.272
12.299
12-329
12-361
12.392
12.424
12.453
12.482
12.51 1
12.541
12.570
12.598
SULPHUR
0 M 0 L S
REGEN
31. 176
31.260
3 1 . 3 50
31.471
31.598
31.719
31.839
31.962
32*077
32*190
32*306
32*402
32.494
32.595
32.694
32.788
32.912
33.027
33. 139
33.265
33-381
33.491
33.601
33.709
33-813
33.91 1
34.014
34. 1 10
FINES IN-OUT
2.760 -0.857
2.776 -0.851
2.795 -0.851
2-814 -0.881
2-833 -0.919
2.851 -0.949
2.866 -0.975
2*881 -
2*897 -
2.913 -
2.932 -
2.950 -
2 • 9 69 -
2.987 -
3.000 -
3.011 -
3*023 -
3*032 -
3*041 -
3.052 -
3*065 -
3.076 -
3.088 -
3.099 -
3.110 -
3.121 -
3.130 -
3.139 -
1 .003
1.026
.049
.078
• 087
.091
. 106
. 109
• 107
• 139
.153
. 167
• 200
.224
• 240
• 254
• 267
• 274
• 276
.281
.277
EQUIVALENT BURNT STON
KILOGRAMS
FEED
3431*9
3442*2
3453*5
3464.5
3473-7
3484.5
3494*7
3504.1
3514.4
3524.4
3533.2
3544.8
3554.5
3564.0
3575.0
3584-2
3592.8
3602.8
3613.0
3619. 5
3627.3
3636- P
3644. 5
3652.3
3662.6
3672.3
3681.4
369?l.6
REMOVED IN-OU
2448*4
2457*5
2467*5
2478.0
2488*4
2498*0
2506*7
2515*4
2524*1
2533*8
2544-5
2555* 1
2565.7
2576.3
2583.7
2590.5
2597.4
2603. 1
3608.7
261 5.3
2622.8
2630.0
2636-8
2643-7
265PI-6
2657. 5
2663.3
2668.9
983-5
984* 7
986*0
986. 6
985»3
986.5
988*0
988.7
990.3
990.6
988.8
989. 7
988.8
987.7
991 .3
993.6
995. 4
999. 7
1 004. 3
1004.?
1004. 5
1007. 7
1008.6
1012-0
101 4. R
1018- 1
-------
I
in
16*1 330
16*1 430
1 6« 1 530
16*1 630
16.1 730
1 6. 1830
16.1930
16.2030
16.2130
16-2230
16.2330
17.0030
17.0130
17.0230
17.0330
17.0430
17.0530
17.0630
17.0730
17.0830
17.0930
17.1030
17.1130
17. 1230
17.1330
17. 1430
17-1530
17. 1630
17.1730
17-1830
17. 1930
17.2030
17.2130
48.707
48*843
48.980
49. 1 1 7
49.255
49 • 39 3
49.531
49.668
49.806
49.943
50.081
50*218
50.355
50 • 49 2
50.628
50.766
50-902
51 .040
51.177
51-314
51 .451
51 .588
51-725
51 -863
52-001
52. 137
52.274
52.407
52.538
52.669
52.800
52.930
53.060
12-627
12.656
12.686
12.716
12.746
12.775
12.804
12.835
12.867
12.902
12.940
12.979
13-018
1 3 • 0 58
13*092
13.130
13.167
13-203
13-239
13.273
13.307
13.342
13-378
13-414
13.450
1 3 • 48 6
13.523
13.555
1 3 • 58 6
13.617
13.648
13.679
13-710
34.210
34-313
34.413
34.512
34.608
34. 709
34.806
34.906
35-008
35.108
35.212
35.318
35.410
35.506
35.616
35.708
35.795
35-883
35.993
36.074
36. 166
36-261
36-35
36.446
36.544
36.647
36-747
36.838
36.936
37.040
37.143
37.239
37.328
3- 148
3.157
3-167
3-176
3- 186
3.197
3.208
3-219
3.233
3.248
3.259
3.271
3.284
3.300
3.312
3.321
3-331
3*340
3.355
3.369
3.393
3 • 40 1
3.410 •
3-417
3-423
3-454
3.460
3.498
3-501
3-505
3-508
3-51 1
3-515
- 1 .278
-1.283
- 1 . 28 6
- 1 . 28 7
-1.285
-1 .288
-1-287
-1-291
-1.302
-1.315
-1 .331
-1 .349
-1.357
-1.371
-1.392
- 1 - 39 4
-1 .391
-1.387
- 1.409
-1 .402
-1 .414
-1 .416
-1 .416
-1.414
-1 .417
-1 .451
-1 .456
- 1 . 48 5
- 1 . 48 6
- 1 . 49 3
- 1 . 49 9
- 1 .499
- 1 .492
3699-8
3707.0
3714.3
3724.0
3734.2
3742-3
3749.6
3758.5
3768.5
3775.7
3784.1
3791 .9
3799.7
3806.5
3812.1
38 1 9 • 1
3826-9
3834.2
3843.1
3853.3
3861 .4
3866.3
3873.8
3881 .9
3890.5
3896.7
3908.3
3923-4
39 38 • 7
3954.6
3964.6
3972.7
3982.7
2674. 4
2680.0
2686. 1
2692.3
2698.4
2705.3
2712.2
2719.0
2728. 1
2737. 1
2744.4
2751.6
2759.9
2769.2
2776.7
2782-4
2788.2
2794.0
2802.7
28 1 1 • 4
2828-0
2833-5
2839.1
2843-5
2847.4
28 69 . 7
2873.7
2898-0
2900.2
2902.4
2904.7
2906.9
2909. 1
1025.4
1027.0
1028-2
1031 • 7
1035-8
1037-0
1037. 4
1039.4
1 0 40 . 4
1038-6
1039.7
1040.3
1 0 39 • 8
1037.2
1035.4
1036- 7
1038-8
1040.2
1040.4
1041.9
1033.5
1032.7
1034.7
1038.4
1043. 1
1027.0
1034.6
1025.4
1038.5
1052-2
1060.0
1065. «
1073- 6
-------
I
(Jl
APPENDIX D - TABLE VII
ANALYSIS OF SOLIDS REMOVED DURING RUN 7
TOTAL SULPHUR WT. PERCENT
DAY. HOUR
2. 1600
4.0800
5.0200
5. 1300
6.0630
6. 1800
7.0400
B.0500
10.0900
1 1 .0700
1 1 • 1900
1 3 . 0 1 00
13. 1000
13. 1900
1 4.2000
15. 1 100
1 5. 180PI
16.1 500
17.1 300
17. 1800
GASIFIER
3.24
3.44
3.45
5.41
5-62
5.5R
5.97
4.33
4-30
4.22
'3.35
3.22
4.0?
5.35
6.39
5.63
4.97
6.04
5.5P
RE GEN.
2.48
2. 1 7
2.22
2.62
2.84
3.46
4. 12
4.61
3.64
2.41
2.60
1 .89
2.07
3.03
3.8?
5. 13
3.78
3. 76
4. 3?
3.94
RE GEN.
CYCLONE
5.83
4.98
4.58
4.34
4.01
4O9
6.45
5.49
4.82
4.12
4*08
4.86
5.70
5-25
5.27
•*r m f-t 1
4.7]
5. 10
4.91
ELUTR.
FINES
4.79
4. 40
3. 19
3.57
3.21
2.96
4.34
4.28
4.43
2.01
4.18
3.68
^.58
3. 12
3.61
? .00
I- * * 7
4.3?
BOILER
BACK
3.81
3-57
3.78
3.45
3.9?
4.91
4.27
4.61
4.71
4.90
3.37
3y f^
• 4?
2.66
3. 1 8
5.79
5r f*
• 50
4.»5
BOILER
FLUE
2.83
2.64
2.98
2.42
2.52
3.32
2.65
2.79
2.45
?»88
2.79
2. 18
2. .dpi
3.41
3.89
4.87
4.0*
3-R 1
O - QO
ELUTR.
COARSE
5.1 1
4.01
4.43
3.67
4. 18
5.43
4.59
5.60
5.30
5.53
5-30
4.88
5. 19
5.07
5.99
6-29
5.8R
5« 3?i
5.87
y r% s**
STACK
K.O.
2.90
3-35
2.86
3.2?
?.66
3.?8
3.96
5.?9
-
-
-
-------
APPENDIX D - TABLE VIII
ANALYSIS OF SOLIDS REMOVED DURING RUN 7
SULPHATE SULPHUR WT. PERCENT
DAY. HOUR GASIFIER
2. 1600
5.0200
5. 1300
6.0630
6 • 1800
7 .0400
8.0500
10.0900
1 ] .0700
1 1 • 1900
1 3.0100
13.1 000
13. 1900
1 4.2000
15.1 100
1 5- 1900
1 6- 1500
17.1 300
17. 1800
0.16
0.14
0.14
0.22
0.15
0.29
0.18
0.24
0.23
0.17
0. 1 3
0.21
0. 1 1
0.12
0.21
0.15
0. 14
0. 19
0. 1 4
0.22
REGEN.
REGEN. CYCLONE
1 .00
0.78
0.63
0.81
0.51
0.77
0.76
0.77
0.80
0.93
0.80
0.95
0.76
0.74
0.78
-
0.87
0.62
0.54
0.73
2.06
-
1 .31
1 .33
1 .00
-
1.51
1 .86
4.34
2.87
2-30
1 .95
2.08
1 .92
2.60
2.56
2.04
1 .53
1 .62
1 .54
ELUTR.
FINES
0.73
0.77
0.63
0.79
0.48
0.46
0.64
0.64
1*14
0.66
0.57
0.39
0.28
0.44
0.29
0.32
0.21
0.32
0.26
0.21
BOILER
BACK
2
1
1
1
1
1
1
1
1
1
0
0
3
2
2
1
1
2
PI
.45
.50
.36
.27
.08
.32
.21
.54
.44
.08
.99
.72
.21
.36
.82
.46
.62
.84
-
.92
BOILER
FLUE
2.07
2.06
1 .99
1 .94
2.06
2.22
2.02
.94
.78
.59
.80
.60
1 .56
1.75
2.55
1 .59
2.46
2.21
2. 17
1 .57
ELUTR.
COARSE
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0.
0 .
0.
19
13
12
23
25
26
23
16
30
31
29
17
1 1
16
18
20
1 7
21
1 4
1 6
STACK
K
1
1
1
1
1
1
1
1
2
.0.
-
. 73
~
*
™
.90
.62
.66
"
• 42
.00
. 1 3
. P4
• 25
-------
APPENDIX D - TABLE IX
m
00
ANALYSIS OF SOLIDS REMOVED DURING RUN 7
TOTAL CARBON WT. PERCENT
DAY. HOUR
2. 1600
4.0800
5.0200
5.1300
6.0630
6. 1800
7.0400
8.0500
10.0900
1 1 .0700
1 1 .1900
13.0100
13. 1000
13. 1900
14.2000
15- 1 100
1 5. 1800
16.1 500
17.1 300
17. 1800
GASIFIER
0.05
0.55
0.51
0.39
0.25
0. 17
1 .54
0.15
0.08
0.06
0.29
0.05
0.06
0. 14
0.28
0.24
0.4]
0.26
PI. 49
0 . 3d ^
REGEN.
0.
0.
0.04
0.
0.
0.
0.
0.
0.06
0.
0.
0.05
0.
0.
0.
0.
ft. 02
PI. 03
0.
0- 16
REGEN.
CYCLONE
2.92
0.71
2.08
1 .53
0.48
0.51
0.80
0.74
0.70
0.24
0.44
1 .10
3.76
1 .32
0.30
0.32
1 .5?
1 .40
ELUTR.
FINES
17.20
9.13
1 1 .00
1 1 .30
1 1 .70
8 .04
15.00
8.37
17.07
22.90
23.40
20.90
16. 18
21 .90
22.50
22.80
23.20
28.60
24 . 40
1 4.00
BOILER
BACK
0. 18
0.03
0.46
0.92
0.30
0.40
0.31
0.44
0.41
0.22
0-23
0. 1 1
0.
0.
0.
0.56
0.46
0.38
•
0.58
BOILER
FLUE
4. 12
3-49
2.67
4.99
4. 1 7
2.99
5.50
2.25
2. 1 5
5.42
6.60
2.00
5.00
12.10
3.25
1 .75
3. 12
8.62
6. 69
3.97
ELUTR.
COARSE
0.40
1 .65
2.67
1 .41
1 .48
2.00
0-20
0-33
1 . SP
• * -J f~
6.08
8.49
1 .90
4.?0
4.6-4
2-56
3*22
3. 72
~J • » C.
5.88
1 . 7Q
. j . if
3.9-a
STACK
K.O.
0.78
1 .04
1 .54
0.70
1 .78
0.40
1 .0?
3.46
0.75
_
-------
APPENDIX D - TABLE X
SOLIDS REMOVED DURING RUN 7* KG. (RAW
DAY .HOUR
1 . 1900
2.0135
2.0450
,0750
,0800
2
2
2.
2.1200
2.1600
2.2000
3.0745
3.1000
3.11?0
3.1545
3.1900
3.2200
4.0030
0330
0530
0700
0800
4i
4<
4.
4.
4
4
4
4.
5.
5.
5.
1 130
1 745
2230
2330
0200
0530
0730
1 150
1 130
1600
2000
5.2330
6.0330
6.0630
1 100
1300
1600
1 700
6.
6'
6
6
A. 2 120
FIFR
.
_
-
-
-
-
„
-
-
_
•»
„
«,
.
_
—
_ .
?.00
^
_
^
_
_
_
m
_
„
^
4.50
—
4.50
^
4.50
4.50
REPEN. REPEN. ELUTR.
CYCLONE FINES
2.75
41.00
41.00 2.25 1«50
38.00
39.00 5.25 2.50
42.50
2.75
61.00 2.00 1.50
32.80 - 1«50
5.50 2.50
_
1 .00
1.20
1 . 50
1 .00
>
1 . 50
-
7.00
1.00
2.00
3.00
M • "
2.00
1 .00 0.50
_
2.50
2.00
37.00
2.00
3.00
1 .00 2.50
• ^ ™
4.50 1.00 3.50
0.50 2»50
4.50
4 . 50
0.50 5.50
4 . 50
POILEP
BACK
-
-
-
-
-
-
-
-
-
-
-
5.00
1 3.00
19.00
22.00
15.00
12.00
-
-
1 3.00
7.00
22.00
-
12.00
7.00
-
9.00
14.00
-
12.00
1 3.00
1 1 .00
1 1 .00
12.00
""
29.00
-
-
4.00
~
POIL^R
FLUF
35.. 00
7. 60
1 0 . 30
~
36.50
"
29.50
20 .00
18 . 50
40 .00
40 .00
20.00
48.00
41 .00
45.00
26.00
25.00
•"
30. 00
-
1 4*00
42 .00
26.00
-
24.00
27 .00
20 .00
35.00
—
31 .00
30.00
29.00
24.00
29.00
•»
24.00
22.00
-
29 .00
*
FLUTP
COARSF
-
-
—
~
-
~
-
-
*
-
-
-
-
-
-
-
-
™
—
5.00
-
-
•
-
3.00
•
-
*
**
_
—
~
•
~
•
-
-
••
•
- 459 -
-------
SOLIDS REMOVED DURING RUN 7, KG. (RAW DATA)
IW.HOUR fiASIFIER REGEN. REGEN.
CYCLONE
7.0140 4.50 4.50
7.0200 - - 0.95
7.0400 4.50 4.50
7.0620 -
7.0650 -
7.1000 4.00 4.00
7.1700 4.00 4.00 0.50
7.2110 4.00 4.00
7.2300 -
8 .0400 - - 0.75
8.0500 -
8.0800 4.00 4.00
8.2300 9.00 9.00
9.0715 - - 0.50
9.0R30 -
9.1230 -
9.1500 -
9.1700 -
9 . 1 8 30
9.2000 -
9.2300 -
10.0245 -
10.0545 -
10.0800 -
10.0945 -
10.1030 -
1 0. 1230 ...
10.1415
10.1700 -..
10.1730 ...
10.1900 ...
10.2000 ...
10.2030 -
10.2130 - - 3.50
10.2300 -
11.0200 5.00 5.00
11.0500 ...
1 1 .0800 ...
1 1 . 1000 ...
11.1245 5.00 5.00
ELUTR.
FINES
—
4.25
1 .00
-
1 .50
_
7.75
-
4.50
4.00
-
1 .00
-
5.00
0.50
-
-
3.50
.
3.50
2.00
3.00
1 .00
1 .00
_
-
-
-
-
-
-
-
3.00
.
1 .00
2.50
1 .00
2.50
1 .50
1 .00
POILFR
RACK
_
1 7.25
_
.
12.00
*•
12.75
24.75
22.00
10.75
1 1 .50
0.50
1 .00
-
.
22.00
12.00
20.00
32.00
24.00
16.00
.
1 5.00
.
44. 00
.
41 .00
_
33.00
.
.
30.50
29.00
31 .00
28.00
13.00
21 .00
POILFR
FLUF
36.00
—
19.50
^
^2.00
40.00
57.00
54.50
12.75
32.50
40.00
54.00
47.00
20.00
42.00
36.00
27.00
38.00
48 .00
47.00
20.00
22.00
48.00
20.00
45.00
P7.00
40 .00
.
17.00
22.75
28.00
24.00
22.00
18.00
25.00
FLUTR
8 .00
0.
20.00
23.00
- 460 -
-------
SOLIDS REMOVED DURING RUN 7, KG. (RAW DATA*
Y.HOUR GASIFIER
1 1 . 1845 5.00
1 | .2200
12.0045 100.00
12.0200
12.0245
12.0330
12.0405
12-0500
12.0540
12.0645
12.0740
12.0R10
12.1210
12.1530
12.1900
12.2215
13*0900
13.1130
13.M30
13.1800
13-1900
13.2015
14.0010
14.0200
14.0315
14.0500
14.0915
14.1245
14.1 400
14.1700
14.1 800
14.2300
14.2345
5.0445
5.0820
5.1045
5.1400
5.1800
5.2015
15.2240
REGEN. REGEN.
CYCLONE
5.00
-
50.00
42.00
50.00
40.00
40.00
40 .00
45.00
45.00
47.00
_
_ j
-
6.00
-
8.00
-
24*00 1 .00
0.50
.
-
-
-
2.00
-
-
-
-
-
-
-
-
-
2.00
-
-
7.00
-
-
ELUTR.
FINES
3.00
3.00
-
-
2.00
-
-
-
1 .00
-
-
2.00
1 .00
0.50
0.50
-
-
-
-
1 .50
-
-
-
-
-
-
-
-
4.00
-
-
1 .00
-
-
3.00
1 .00
1 .00
1 .00
1 .00
-
BOILER
BACK
50.00
36. 0P
-
-
32.00
-
-
-
1 4.00
-
-
14.00
28.00
37.00
64.00
93.00
101 .00
212.00
67.00
55.00
42.00
25.00
27.50
-
-
65.00
60.00
46.00
-
60 .00
-
32.50
50*00
65.00
—
R4.PI0
63.00
60.00
44.00
50.00
BOILER
FLUE
50.00
31 .0P>
-
-
28.00
-
-
-
1 1 .00
-
—
1 4.00
2R.00
25.00
31 .00
30 . 00
90.00
R.00
1 6.00
-
22.00
~
••
3C* .00
*-
—
3/1.00
•
19.50
•"
12.50
9.00
"
26.00
""
3R.00
1 4.00
19.00
1 1 .00
-
ELUTR
COARSE
-
-
-
-
-
-
-
-
—
•
—
-
—
—
—
-
-
-
—
••
•*
^
™
™
™
*
**
"
—
"
~
••
—
••
~
-
-
-
-
-
- 461 -
-------
DAY.HOUR
1 5.P330
16.01 30
1 6.040(7)
16.0R00
1 6. 1045
16.1415
16. 1730
16.2030
16.2230
17.0100
0300
0500
0630
0R30
17
1 7
17
17
17.1 145
17.1615
1 7.1R20
17.2200
20.1200
25.1200
SOLIDS REMOVED DURING RUN 7* KG.
-------
APPENDIX D - TABLE XI
RUN 7 - STONE FEED
SIEVE SIZE IN MICRONS
MUMPER
DAY- 3200 2800
TIME 2800 1400
1 400
1 180
1 180
850
850
600
600 ?50 1
250 150 1
50 1 PIP1
P0
WT. PERCENT.
509?*
509?*
509?*
5099*
5092*
50926
50926
5092*
50939
509 3R
50926
5094R
51007
5100R
51017
50926
50926
509?6
51035
51044
51026
51 02*
5102*
51 02*
•_/»''*
51055
51 057
50164
5102*
501 69
50927
5108?
51090
50927
51 100
511*1
,.l 1 t * *
50927
511**
51 I??
1 .0830
1 . 1R00
1 .21 45
2.0030
3.0900
3. 1 200
3. 1 500
3. 1 *00
4.0600
4.01 30
4. 1200
4.2330
5 • 0 30 3
5.0730
6.0300
6.1315
6.1715
6.1715
6. 1800
7 .0400
7.0510
8.0230
8.0620
9.0?00
9. 1030
0.0900
t .0700
1 . 1 600
1 .0700
1 . 1600
1 . 1900
2.0100
12. 1 1 45
1 3. 1900
5. 1800
5. 1 100
5. 1 500
6. 1 500
7. 1 300
8.9
8.2
.9
.8
3. 7
1 .9
.6
. 1
• 6
.2
.7
.3
.8
.7
1 .7
.6
1 .0
1 .2
1 • 1
.9
.0
.0
.0
.0
. 1
.0
. 1
. *
.9
. 4
1 .9
.0
.0
.0
.0
.0
.0
.0
. 1
24.8
56. 1
57. R
56.4
63.4
63.2
57.5
64. R
60.9
64.6
62.9
60.5
57.7
54.6
47.3
56. R
70. 1
61 .R
7?. 9
45-8
21 .9
19.0
22.4
20.6
24.4
48.2
33.2
47.3
57.8
44.5
66.6
9.2
12.6
8. 1
15.0
12.5
1 7.0
9.5
10.7
5.3
10.3
11.6
12.5
10.1
10.0
10.5
9.8
1 1 .5
9.9
9.2
12.1
9.7
17.7
9.4
13.4
3.7
11.7
9.0
15.6
11 .3
12.6
11.4
11 .2
15.9
1 1 .2
12.4
13.5
12.2
14.9
10.3
9.2
12.1
9.8
11.1
9.6
12.8
9.6
9.5
9.3
18. /i
21 .5
22.7
18.2
18.0
21.6
1 7.4
22. 1
18.3
18.4
20.3
23.0
21 .PI
17. 1
21 .8
18.1
18.8
1 5-9
20.8
21 .5
24.4
22.2
22.3
29.9
21 .8
23.1
27.9
20.7
29.3
16.0
22.3
29.4
29.5
31 .9
19.9
23.8
21 .1
21 .7
8.7
5.5
6. 1
5.8
4.0
5.8
7.5
5.2
4. 1
5.3
6.8
4. 7
7.8
4.8
8. 1
6.5
5.7
5.3
. 3
8.3
19. 1
19.7
17.9
19.0
19.2
10. 1
1 7.9
8.9
6.5
9.4
4. 7
20.5
17.0
24.7
17.4
19.6
18.6
22.4
19.9
?9.8
. 7
1 .3
.8
.0
. 7
.8
. R
.5
. 4
.7
.7
.5
.6
7.3
.5
.«
1 .0
. 4
4. 3
?5.7
?3«9
?5.8
O £L. ^
r. O * ~j
7.6
5« R
1 3.?
1 .0
1 •?
1 . 1
. 3
34.8
20.4
25.3
23. 1
35. 1
?6. 3
35.5
35. 1
7. 3
. 1
. 3
•?
.0
. 1
. 1
. 1
.0
.0
.PI
• P
. 1
. 1
1.5
. 1
.0
. 3
. PI
. 5
.0
. 0
.0
. 0
1 .?
1 » 5
.0
*P
*P
D.
• 0
?. 3
5.0
. R
.8
1 .4
.9
1 .4
?.?
P.f. ?.?
.1 • /
.2 . /i
.0 .^
.PI . S
.0 .?
.W .3
• 1 -(
.0 .3
.0 .P
.Pi .3
. P1 .3
.1 • 'l
.] .3
.1 7.5
.P .3
• 0 • o
. \ . O
1.--1
. '
.0 ~* • ';
.PI . /'
.0 • A
. P) . ?
_— r:
.Pi .5
4 « T
.1 1.7
. A \ • V
1*
• 1
/"> ^L
. P1 • r>
. t ' ^
.0 ?
1 . 1
• 1 * 1
1x r?i
. * . ">
.Pi 7 . 4
. ? ! » 5
?/
• f>
. ? 1 . *
.4 . 3
.1 .5
. P .A
- 463 -
-------
I
a\
I
APPENDIX D - TABLE XII
RUN 7 - GASIFIER BED
SIEVE SIZE IN MICRONS
SAMPLE
NUMBER
51001
51009
51027
51036
51061
51
bl
51
51
51
bl
51
33
46
56
-46
65
84
70
DAY- 3200
TIME 2800
5-0200
5. 1300
6. 1800
7.0400
10.0900
13. 1900
15. 1 100
15. 1800
15. ] 100
16. 1500
1 7. 1800
17.1 300
.5
.0
• 0
.0
.2
.0
.0
.0
.0
.0
.0
.0
2800
1 400
37.0
30. 1
28.9
23.4
27.2
22.4
16-?
16. 1
16. 1
15.0
12.5
13.2
1 400
1 180
1 180
850
WT- PERCENT.
14-1 20.3
16.9 21 . 1
10.7 18.5
10.2 19-2
11.7
1 5.8
1 3.8
13.8
14.3
13.9
11.7
13.2
20.0
27.6
27.9
28.6
28.4
28.6
27.7
22.9
850
600
16*1
17.2
20.8
21 .8
18.5
19. 7
23. R
23- 4
23-4
23.6
24. 4
26. 1
600
250
12.0
1 4.7
20.9
25.2
2?. 2
14.5
18. 4
18.0
1 7.8
1R.R
23.6
24. 7
250
1 50
.0
.0
.0
• 0
.0
.0
• P)
.0
.0
. 1
.0
.0
150
100
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
.0
100
.0
.0
• 1
. ?
.2
.0
.0
.0
.0
.0
.p
.0
-------
en
I
APPENDIX D - TABLE XIII
RUN 7 - REGENERATOR BED
SIEVE SIZE IN MICRONS
SAMPLE DAY-
NUMBER TIME
3200
2800
2800
1400
1400
1 180
1 180
850
850
600
600
250
250
150
150
100
100
WT. PERCENT-
5(71941 4.0800
51060
50
51
51
51
5 i
51
70
47
57
6/>
7 1
«5
0.PI900
1 .0700
5.0000
5. 1800
6. 1 500
7. 1300
7. 1800
.0
• 3
.0
.0
.0
.0
.0
. 1
36.6
26.6
34.2
17.1
15.7
1 3.9
12.9
1 3.8
12-8
10. 7
12.8
13-6
1 3-6
12. 8
12.8
13. t
21 -2
19-7
22.0
28.2
28. 5
?*.8
27.6
27. 0
15.8
19. 1
1 7.7
23.4
23.0
23*9
24.4
23-5
1 3.6
23.3
1 3»0
1 7.6
19. 1
P<* . 4
22. 1
PP. 4
.0
.0
• 3
• 1
.0
.Pi
.0
.0
.0
.0
. 0
« 0
. C?l
. 0
• 1
. 0
.0
• 3
• v\
• 1
. 1
-------
APPENDIX D - TABLE XIV
RUN 7 - BOILER BACK END
SIEVE SIZE IN MICROMS
I
ON
I
SAMPLE DAY- 3200
NUMBER TIME 2800
2800
1400
1400
1 180
1 TR0
850
850
600
600
250
250
150
150
100
100
UT. PERCENT-
51058
51067 ,
51094
51 163
51 1 73
5J 18?
0.
1 .
3.
6-
7.
7.
0900
0700
1300
1500
1300
1800
.0
.0
.0
.0
.0
. 1
5.1
.2
21 .9
4.5
3-0
1 -A
2. 7
1 .3
12.9
5.0
3.8
1 • «
4. 4
11.4
21 .7
15-2
11.7
8.6
9.3
26.3
1 4. 1
19.0
21 . 1
19. 3
62. *
57.0
22. 1
45.9
53.3
67. 7
.2
.9
2.6
5.5
4. 1
.2
.2
.0
1-3
2. 7
1 • 3
• 4
1 5.2
2.R
3-3
2. 1
1 . 7
. 4
-------
APPENDIX ,D - TABLE XV
RUN 7 - ELUTRIATOR COARSE
SIEVE SIZE IN MICRONS
SAMPLE
NUMBER
DAY-
TIME
3200
2800
2800
1400
1400
1 180
1180 850
850 600
600
250
250
150
150
100
100
WT. PERCENT.
50947
50950
51015
51024
51038
51062
51068
51126
51083
51 148
51 160
51 168
51 178
51062
4.0800
5.0200
5-1300
6.0630
7.0400
0.0000
1 .0700
3-1900
3-0100
5-1 100
5- 1800
16. 1500
17. 1800
10.0900
.2
.2
• 1
.0
.0
. 1
.0
.0
1 .4
.1
• 1
.0
.0
.0
12.8
6.4
7.9
3.3
3.8
16.9
7-9
2.1
2.2
3.6
4.0
2.0
.9
14.3
6.0
3.0
3.9
1 .3
1.7
6.6
3-7
2.3
1 .7
4. 1
4.6
2.8
1 .3
5.5
12. 1 14.5
2.7 12.4
7-9 7.1
3-3 5.7
3.5 6.7
1 1 .2
9.7
6.7
5-2
1 1 .0
1 1 -9
7.6
1 .7
3-8
0.2
7.5
4.2
4.6
1 -4
3.9 6.5
10.3 10.3
43.8
36.9
42.6
2.3
66.5
42.4
40.9
59-3
75.2
50.2
54.0
54.6
37.9
33.7
3. 1
8.8
3.0
1.3
.0
.6
• 3
. 1
.0
.0
. 1
.0
.2
8.5
2.9
-2
1 .0
18.0
.8
. 1
2-9
.0
3.?
1 .3
5.5
2.3
14.3
5- 1
4.8
29. 4
26.6
64. 7
17. 1
10.3
20.9
19.4
3.5
1 5.5
5- 1
19. 3
35.P
12.4
-------
Page 1 of 2
APPENDIX D - TABLE XVI
CAFB Stack Cyclone Fines (Sample 1)
Dry sieving with 2QO mesh sieve;
+74 microns = 18.7O gm = 19.06%
-74 microns = 79.41 gm = 8O.94%
»tal Sample* 98.11 gm =
* 100. 00%
iHCO Analysis: - 74 micron fraction
Throttle
No.
18
17
16
14
12
8
4
**
Upper Size
Microns
1.2
1.9
4.2
7.0
10.0
18.0
3O.O
74.0
+74
Weight
gm
0.25
1.65
9.15
11.80
11.60
15.20
5.10
24.66
microns
Per Cent
0.25
1.68
9.33
12.03
11.82
15.49
5.20
25.14
80.94%
19.06%
Cumulative % less
than stated size
0.25
1.94
11.26
23.29
35.11
50.61
55.80
80.94
Total = 1OO.OO%
- 468 -
-------
Page 2 of 2
APPENDIX D - TABLE XVI
CAFB -Stack Cyclone Fines (Sample 2)
Dry sieving with 20O mesh sieve;
+74 microns = 21.84 gm = 21.67%
-74 microns = 78.93 gm = 78.33%
Total Sample = 100.77 gm = 1OO.OO%
BAHCO Analysis: -74 micron fraction
Throttle Upper Size Weight Per Cent
No. Microns gm
18 1.2 0.24 0.24
17 1.9 1.74 1.73
16 4.2 9.64 9.57
14 7.0 12.01 11.92
12 10.0 12.28 12.19
8 18.0 16.05 15.93
4 30.0 5.32 5.28
74.0 21.65 21.48
78.33%
+74 Microns 21.67%
Cumulative % less
than stated size
0.24
1.97
11.53
23.45
35.64
51.56
56.84
78.33
Total = 100.OO%
- 469 -
-------
C. A.F B. RUN 7
IOO
5-00
6OO
7 OO
8OO
900
IO-OO II-OO 12-00
FIG. 025 SHEET.I.
-------
C.A.F.B. RUN 7 (Contd)
16-00
1700 18-00
FIG. D25 SHEET 2
- 471 -
-------
100
£20
O
IT
O
I
UJ
y
C/3
10
8
P 6
< 5
a.
4
3
I
1
0-01 0-1
C. A.F.B. CYCLONE FINES
SAMPLE NO. I
» 3-02g/cm'
1
1
1
1
I 10 30 50
% LESS THAN STATED SIZE
1
70 90
FIG.D26
- 472 -
-------
100
C. A. F. B. CYCLONE FINES
SAMPLE NO. 2
3-02g/cm*
in
g 20
DC
o
i
UJ
o
H
S
Q.
10
8
6
5
4
1
1
1
1
0-01 0-1
I 10 30 50
% LESS THAN STATED SIZE
- 473 -
70
90
FIG-D27.
-------
APPENDIX E
CAFB PILOT PLANT OPERATING PROCEDURES
A. PREPARATION FOR RUNNING
1. Operation of Services
(a) Oil Ring Main
• Check tank contents.
• Check outflow temperature is about 140/150°F.
• Start compressor/oil pump on boiler by switching
on at panel. Do not run for more than 5 seconds
at first few runs in order to set thick oil
moving. Continue until temperature gauge on
outflow heater reaches 2OO/21O<)F and then pump
may be left on.
• The boiler heater circuit is now on automatic
operation and is ready for use.
(b) Kerosene
• Stored in 5OO gal. tank - check that there is
enough for anticipated usage. First check that
isolating valve is turned off on pump supply
feed pipe. Then open valve at barrel.
(c) Nitrogen
• Stored in liquid N2 tank check that there is
sufficient for anticipated usage.
• Check all valves are turned off at the bleed
locations on gasifier before opening valve on
manifold.
(d) Propane
• Stored in 2 banks of cylinders outside building.
- 474 -
-------
• Commence runs on the bank with least available so
that replacement bottles may be ordered in
reasonable time. Warn Purchasing at least 7 days
prior to anticipated use and thereafter replacements
can be obtained on 48 hours notice. Only turn on
outside valve immediately prior to use for safety
reasons.
(e) Boiler and Cooling System
(1) Cooling System
• Open drain valve on cooling pump delivery which
bleeds water to waste.
• Go up on roof and check valve is open on water
feed to cooler - listen to check that water is
flowing. If not - check all valves back to
tower.
• Turn off valve on drain to conserve water until
heating takes place.
• Warn Services of an anticipated soft water usage
maximum of 50O gph. Please give as much notice
as possible.
• Turn on secondary side i.e. cooler pump - hold
button in for at least 1O seconds to prevent a
shutdown alarm.
• Turn on boiler circulating pump. No button to
hold on this circuit.
• Turn on supply to cooler fan located on end wall
(main stores end) n.b. fan is thermostatically
controlled and will not cut in until pond water
reaches 1OO°F.
• Check temperature setting of automatic mixing
valve is set to 180°F and turn on electrical
supply to valve. (Controller set on wall by
pressurisation unit).
(2) Pressurisation System
• Check water level in storage tank is at rubber
band marker and make up is turned on.
- 475 -
-------
• Check nitrogen bottle pressure is above 500 psi.
• Turn on pressurisation system and check that
pressure reaches 50 psi approximately. On start
up bell will ring, cancel bell, then turn off N2
at cylinder.
(3) Boiler
• Check that main flue butterfly valve is at marked
position. (Do not take any notice of 'open1 and
'shut1 marked positions as this was incorrectly
fabricated).
• Check that water pressure in boiler is approx-
imately 50 psi.
• Check that any sampling lines are correctly
installed in flue.
2. Preparation for Running Gasifier
(a) General Check
• Carry out general inspection to ensure all main
supply lines are complete and that no sampling
or other instrumentation holes have been left
open.
• Check condition of all drive belts.
• Check oil level in metering pumps, drain all air
filters for moisture.
• Check all sampling pumps work.
• Check all analytical equipment and calibrate if
necessary.
(b) Control Unit
• Set alarm switch to "all alarms will show" position.
• Set alarm bell to "mute".
• Set automatic shut down switch to "inoperative"
position.
- 476 -
-------
Turn on main power supply.
"Burner or Boiler water" and "regenerator low bed"
warning lights should come on. The former alarm is
caused by pilot flame being out.
Turn on regenerator blower and check that it will
shut down if "automatic shut down" is selected.
Reset alarm panel. Replace switch to "shutdown
inoperative".
Check that original two alarm lights show.
Check and fill manometers if required.
Start bleeds on injectors using direct N2 bypass to
avoid starting Compton compressors.
Set pilot burner air supply to 6 cfm, turn on propane
at external manifold, at plug cock on the wall, at
valve over pit. Start main burner blower to
pressurise plenum. Turn on pilot operating switch.
The pilot should light and lock on. The pilot
should stay alight and the warning light on the
control panel go out.
Set up recorders to 2O psi air supply. Switch in
charts to check movements and recording pens are
working. Turn off charts until required. Switch is
in back of panel - plug and socket on each recorder.
B. WARM UP
The gasifier is heated over a 3 day period with a rate of
temperature rise of about 12°C per hour.
It is important that heat be passed through the regnerator to
make heat up of the refractory as uniform as possible. To
secure a gas flow through the regenerator, the regenerator
outlet valve must be open wide and the main boiler outlet tube
damper closed. Be sure there is a nitrogen bleed through
all injectors and pressure taps before starting.
The heat up sequence is as follows:
1. Start second stage air blower and line up 20O CFM air
flow to gasifier. Remote valves set as follows:-
- 477 -
-------
1st Stage outlet Closed
2nd Stage inlet Open
Flue Gas Recycle Closed
2. Turn on regenerator blower and set flow to about 3 CFM
through regenerator.
3. Open air flow to fuel injector lines. Set to 5 CFM on
each injector.
4. Start air flow to boiler main burners - Set to 9OO CFM.
5. Turn on propane supply up to gasifier start up burner.
Set ganged propane valve to "start" position.
6. Line up air flow to start up burner.
7. Turn on cooling water spray to gas burner casing.
8. Turn on electrical power to start up burner control and
start burner.
9. Adjust propane air/fuel ratio to obtain about 3 times
stoichiometric air to fuel.
10. Monitor temperatures and adjust main and regenerator
dampers to obtain uniform temperature rise in gasifier
and regenerator.
11. Adjust gas and air rate to burner to follow desired
temperature schedule on TC 7 of the L & N Recorder
(gas space below Lid).
12. Do not let air rate to distributor of gasifier fall
below 1OO CFM. When necessary, increase total air
supply to gasifier. Remember that air to distributor
is difference between total air and air to burner.
13. When gasifier temperature reaches 7OO*C begin kerosene
firing. Do not start kero firing without technical man
on unit with operator.
14. Kerosene should be cut in very slowly at first, one
pump at a time, to avoid upset to temperatures. Once
kero feed is started, gradually raise kero rate to
follow temperature schedule to 850°C. Air rate to
plenum may have to be increased to provide sufficient
air for kero combustion. There should be at least 3O CFM
air through the plenum for each gallon/hr of kerosene feed.
- 478 -
-------
15. When gasifier temperature reaches 85O°C begin reducing
gas and air to burner while increasing kero and air
to gasifier to maintain temperature. Gas rate should
be reduced to about 1OO CFM, burner air to about 6O CFM,
and total air about 350 CFM.
16. Fill limestone hopper while heat up is in progress.
17. Start air flow at 5 CFM to limestone feed system.
18. Start limestone feed vibrator at low setting (about 1)
and begin adding stone to unit. Do not start limestone
addition without technical man present.
19. Observe temperatures and fluidisation as soon as
limestone addition starts to be sure that stone is
being heated and fluidised throughout. If necessary
adjust air and firing rates to obtain uniform heat up.
Avoid letting stone temperature fall below 800°C.
20. Gradually add limestone to reach specified bed level on
manometer. Do not exceed specified vibrator setting
while adding bed, or fill line will block.
21. Start Compton compressors, raise regenerator air flow to
15 CFM, and begin bed circulation between gasifier and
regenerator as soon as bed depth reaches 1O in. w.g.
22. When bed level reaches 12 in. w.g. the start up gas
burner can be turned off. Start a 4 CFM air flow
through burner cooling inlet to keep burner head cool
and block main air line to burner.
C. INITIATING GASIFICATION
When the gasifier is at operating temperature with a desired
bed level established and circulating/ gasification can be
started. The procedure used is to switch from kerosene
combustion to fuel oil combustion, increase oil rate to the
stoichiometric ratio to eliminate oxygen from the system, and
then increase oil rate to that required for gasification.
1. Starting point is with gasifier at about 850°C with at
least 12 in. w.g. bed depth, and good solids circulation
in both directions between gasifier and regenerator.
Temperature is maintained by kerosene combustion in the
bed with excess air.
- 479 -
-------
2. Increase air flow to main burner to 110O CFM total of
which 150 CFM is passed through the premix nozzle.
3. Check that pilot flame is strong and stable. Do not
proceed until it is.
4. Check cooling system to be sure it is operating
satisfactorily.
5. Line up flue gas recycle and adjust total flow to
gasifier plenum to 260 CFM; 3O CFM flue gas recycle
and 23O CFM fresh air.
6. Stop oil pumps and switch pump suction lines to fuel
oil supply from kerosene supply.
7. Set centre pump to deliver 78 Ib/hr fuel oil (stoichio-
metric) and start pump.
8. Set pumps 1 and 3 to deliver 130 Ib/hr fuel oil each,
and when gasifier bed temperature reaches 90O°C, switch
on both pumps. Normally pumps 1 and 3 will be required
about 15 seconds after starting pump 2 at stoichiometric
oil rate.
9. Main boiler flame should ignite within about 15 seconds
of starting pumps 1 and 3.
1O. Raise pump 2 setting to deliver 13O Ib/hr fuel oil.
11. Adjust flue gas recycle rate to control temperature at
desired level.
12. Check that cooling tower fan starts when secondary
water temperature reaches the set point.
13. Begin limestone feed addition.
14. Bring all conditions to running specifications.
- 480 -
-------
D. SOLIDS HANDLING
1. Bed Replacement
It is necessary to add fresh bed to the gasifier to maintain
efficiency of operation. If required, material may be
removed from the regenerator through a valve which can be
operated on an automatic cycling basis from a variable
controller. The fresh bed material is supplied to the
gasifier through a feed pipe which passes through the side
wall and enters the bed about 61 cms (24 ins) above the
distributor. The stone is fed from a storage hopper onto
a vibrator and then dropped into the feed pipe to be
transported in a dilute phase with air. The feed hopper
and vibrator are contained within a pressure vessel which is
purged with nitrogen and maintained just above gasifier
pressure to prevent the back flow of gasifier products which
could lay down tar in the feed system. The feed hopper is
continuously monitored with a remote reading load cell so
that the bed feed rate can be accurately controlled at all
times. The hopper can be refilled from an upper lock hopper
without stopping the feed to the gasifier thus maintaining
constant conditions in the unit. The upper lock hopper is
filled by dilute phase material transfer from a small
storage hopper on the ground into which the bags of stone
are emptied.
2. Bed Removal
Hot bed material may be removed from the regenerator by
automatic operation of the plug valve on the regenerator
drain, setting the valve opening time to achieve the desired
material removal rate. Frequent short periods of drainage
are preferable to long periods followed by long periods
without material movement because blockages are more likely
to occur in the drain pipe. Gasifier bed material can be
removed by manual operation of either the upper or lower
drain valves.
3. Draining Regenerator Cyclone
The regenerator cyclone fines could be drained externally in
Runs 5 and 6. Provision was made in Run 7 to feed the fines
back into the gasifier cyclone fines into the gasifier bed
with manual external draining available if required. The
frequency of draining the material is determined by the
running conditions but in all circumstances the material is
removed by a lock hopper system to prevent the release of S02-
- 481 -
-------
Provision was made to include a pneumatic rapper on the
regenerator cyclone which comprised of a small metal
hammer which struck the cyclone opposite the gas entry port,
at regular intervals to prevent the adherence of fine dust.
4. Gasifier Bed Sampling
Samples of bed material may be taken from the upper or lower
drain points taking care to flush the line of residual
material and purging with nitrogen before collecting the
sample.
E. CARBON BURN-OUT PROCEDURE
The carbon burn out procedure is initiated when the pressure
in the gasifier above the bed reaches approximately 60 cms
w.g.
1. Preparations
(a) Preparations should be started as soon as there are
signs of the pressure build up increasing its rate of
change. Additional help should be called out if
required.
(b) Connect recycle and nitrogen supply pipes to the lid
and check that the valves are closed.
(c) Install gas sampling lines from the plenum and lid
recycle pipework to 02 and C02 meters.
(d) Shut off any air bleeds to the lid.
2. Bed Sulphation
(a) Shut off bed feed, nitrogen to hopper purge and shut
hopper outlet valve.
(b) Reduce gasifier temperature to below 85O°C by increasing
flue gas recycle rate.
(c) Switch bed circulation to manual and increase the rate
to lower the regenerator temperature below 1OOO°C if
possible.
- 482 -
-------
(d) Check that the automatic control on the cooler water is
functioning and the set point is at or just above the
boiler water return temperature.
(e) Disconnect sample lines to boiler SO2 analysis and clip
off so that other analysers cannot suck air.
(f) Shut outlet valve on boiler sampling cyclone to prevent
backflow of air into the boiler gas sampling system.
(g) Disconnect both orifice plate gauges on the 1st stage
blower inlet to prevent liquid being blown out of the
instruments.
(h) Open the by-pass on the flue gas recycle orifice plate.
(j) Shut off air to the gasifier start up burner purge.
(k) Switch fuel injectors to nitrogen and shut off air into
the bed feed.
(1) Shut off fuel to the gasifies by stopping the pump and
closing the isolating valves on the feed lines.
(m) Shut off air to the main burner when the main flame has
gone out by closing the valves - do not shut off the
blower.
(n) Watch the pressurisation unit pressure and be prepared
to maintain pressure above the low level alarm by
nitrogen addition if required.
(p) Close the scrubber gas return valve to provide maximum
recycle supply and open recycle valve fully securing
plugs across the 1st stage air inlet orifice plate.
Watch the gasifier distributor pressure drop to assess
the flow rate through the bed and if possible maintain a
higher pressure in the gasifier than the regenerator.
(q) Turn on the nitrogen supply to the lid and reduce water
supply to the scrubber to give a pressure drop of
approximately 20". The water may need a further
reduction if there is an inadequate flue gas recycle
supply.
- 483 -
-------
(r) Control the bed temperature to 925 - 95O°C by
regulating the flow of air to the main burner which
should be set initially to provide about 10% 02
concentration in the gas stream.
(s) When sulphation is near completion the bed temperature
will start to fall and the duct temperatures rise due
to the breakthrough of oxygen. At this point shut down
the gasifier blowers, close the gate valve on the plenum
supply pipef disconnect the plenum sampling line and
reduce the regenerator air flow to 3 cfm.
(t) Shut off air to the main burner by closing all the
valves.
(u) Shut off the nitrogen with the fines return system.
3. Carbon Burn-out
(a) Restart the gasifier blowers and open the valve in the
lid recycle line, adjusting the flow to about 10O cfm.
(b) Adjust oxygen concentration to about 7% by bleeding in
air using the main burner air supply system.
(c) Gradually increase the rate of recycle to ISO cfm but
maintain duct temperatures below 1OOO°C by controlling
the oxygen concentration to prevent damage to the unit.
(d) Burn out is complete when the duct temperatures start
to fall, the operation may take some hours depending
upon the amount of carbon to be removed. The gasifier
bed temperature will gradually fall during this period
and should not go below 60O°C at the bed centre other-
wise there will be difficulty in restarting with
kerosene combustion. It is possible to give the bed
a short temperature boost by fluidising and feeding
kerosene but duct temperatures will rise sharply and
great care must be taken.
(e) When burn-out is complete close the valve in the line
to the lid and shut off the blowers.
(f) Restart on kerosene combustion with a fluidised
gasifier bed.
- 484 -
-------
(g) Prepare to inspect the boiler rear end and commence
the check out for resumption of gasification.
(h) Just prior to gasification drain out the chunk traps
in the cyclone drain pots and inspect the cyclones
through the top access holes to ensure that the drain
lines are not obstructed.
- 485 -
-------
APPENDIX F
CAFB PILOT PLANT ALARM SYSTEMS
1, ALARM ACTIONS
The installation is protected by a number of safety detection
systems and there are four main actions that may be triggered
off by an alarm depending upon which alarm is energised.
(a) Alarm Action A
• Fire Valves Close on oil line flow and return at
entry point into the building.
• Oil circulation pump stops.
• Gasifier control panel is alarmed - the consequences
of this alarm may be controlled and are described
below.
• Interior and exterior bells ring inside and outside
laboratory.
• Red light comes up on auxiliary panel located on
laboratory wall close to main door to 3A.
(b) Alarm Action B
• Gasifier control panel is alarmed - consequences of
this alarm may be controlled and are described below.
(c) Alarm Action C
• Alarm light comes up on auxiliary panel.
• Interior and exterior bells ring inside and outside
laboratory.
(d) Alarm Action D
• Alarm light only comes up on main control panel.
- 486 -
-------
(®) Choice of main control panel action
There are various actions that may be preselected to follow an
alarm signal to the main control panel.
• An internal bell can ring or may be made inoperative
by a switch on the panel.
• Automatic shut down of all blowers, pumps, compressors
except burner air supply which is manually controlled
at all times. Alternatively this procedure can be
made inoperative by a switch on the panel.
• All alarm sensors may show as lights on the panel when
alarmed.
• The first alarm sensor only will show as a light
and any other alarms which are energised as a
result of the automatic shut down will not show.
• The low hopper alarm has been arranged to show a
warning light only and cannot be arranged to sound
a bell or cause shut down.
Generally it is proposed to run the unit with the alarm bell in
circuit and automatic plant shut down selected - this is
necessary because failure of the gas pilot flame could result in
unburnt gas forming in the boiler and ultimately an explosion.
(f) Method of alarm display on main panel
The particular alarm might well be dependent upon the source of
the alarm. Table F-l lists the alarms and how they will be
shown.
2. * ALARM SYSTEMS
The installation is best considered as four main systems:
• The boiler and its cooling system
• The gasifier
• The experimental burner on the boiler
• General alarms
- 487 -
-------
(a) The boiler and cooling system
The water in the boiler circuit is pressurised to 5O psi and
pumped through a heat exchanger. The secondary side of the
heat exchanger is pumped to an evaporative cooler located on
the roof of the building. The following alarms are installed
in this system.
(1) Failure of the cooler circulating pump will operate
a differential pressure switch across the pump feed
and delivery lines -
Result - Action (A) above
(2) High water temperature in the cooler water feed
line - set to operate at 19O°F.
Result Action A above
(3) High water temperature in the boiler - set to
operate at 245°F.
Result Action B above
(4) Low pressure in the pressurisation unit - set to
operate at 43 psi.
Result - Action B above
(b) Gasifier
The gasifier has many alarm circuits whose action has been
described earlier. The following parameters are monitored:-
(1) High temperature in the gasifier bed - set to
95O°C. Shown and alarmed from Guardian indicator
on main panel.
(2) High temperature in regenerator bed - set to 11OO°C,
Shown and alarmed from Leeds and Northrup recorder.
(3) Gasifier distributor blocked - shown on switch
and set to 15".
(4) Regenerator distributor blocked - shown on switch
and set to 15".
- 488 -
-------
(5) Regenerator bed low level - shown on switch and
set to 10".
(6) Regenerator bed high level - shown on switch and
set to 24".
(7) Down stream blockage indicated by pressure in
gasifier gas space - shown on switch and set to
10".
All these alarms Result - Action B
(8) Hopper low level will cause a warning light only
on panel.
Result - Action D
(c) Experimental burner
The experimental burner will cause an alarm signal if there
is a failure of:-
• pilot flame
• main flame
• low gas pressure set to 4" w.g.
• low air plenum pressure - set to 2" w.g.
• low pilot air pressure - set to .3 psi
Any one of these alarms will shown as alarm J on main panel.
Result - Action B
(d) General Alarms
(1) Fire Detector
A fire detector is situated over the boiler and
will alarm at 15O°F.
Result - Action A
(2) Sump Level
In the event of the build up of liquid in the pit
to about 1" deep over the floor of the pit an
alarm will sound.
Result - Action C
- 489 -
-------
3. RESTART PROCEDURE
In the event of an alarm showing it is important to determine
the cause of the alarm and if it is safe to restart.
(a) Restart after Action A
(1) Gasifier
The gasifier restarting procedure is described in
the operating section, Appendix E.
(2) Auxiliary Panel
• If the audible alarm has not been muted it may
be done by pushing the mute button on the
auxiliary panel.
• The panel may be reset as soon as the alarm
signal has ceased and the red light will go out.
• The two fire valves must be reset by lifting the
lever and releasing the rewind mechanism by
raising the rubber covered lever on the side of
the panel and tightly winding up the string in
a clockwise direction until the levers are set
up as high as possible. The rubber covered
levers can now be switched down. The oil
circulating pump is restarted by depressing the
green button on the side of the starter located
near the pump.
(b) Restart after Action B
Gasifier
The cause of the alarm must be established before restart
according to the instructions listed in Appendix E.
(c) Restart after Action C
Assuming that the automatic shut down was operative for main
flame failure, the plant should be put under static conditions
by shutting off the plenum air valve and turning nitrogen to
all air injection points using minimum flow to retain bed
temperature. Check pilot flame and flame scanners for
correct operation and when all is functioning restart as
described in Appendix E.
- 490 -
-------
(d) Action D and E
These alarms will not cause a shutdown and are intended to
draw the attention of the controller to some change in unit
conditions which could develop into a problem if ignored.
(e) Action G
This alarm will have caused a shut down and the unit should
be put under static condition with nitrogen bleeds when
appropriate. Investigation should be made into the cause of
low pressure, i.e. pump failure, valve leaking, or boiler
water circuit leak. When the cause has been established and
the problem resolved the unit may be either sulphated and
burnt out or restarted as described in Appendix E.
- 491 -
-------
Table F-l
Summary of Pilot Plant Alarm System
Source of Alarm
1. Failure of water circu-
lating pump.
2. High water temperature
on cooler feed line
3. High water temperature
in the boiler
8
Auxiliary
Panel
Red Light
Red Light
and bells
None
None
Low Pressure in
pressurisation unit
n.b. Red light shown on
panel, and its own
Gasifier high None
temperature
Regenerator high None
temperature
Gasifier distributor- None
low pressure
Regenerator distributor- None
high pressure
9. Regenerator low bed None
level
10. Regenerator high bed None
level
11. Gasifier high pressure None
Main Control Panel
Red light titled
"Auxiliary Panel"
Red light titled
"Auxiliary Panel"
Red light titled
"Boiler water or
Burner"
Red light titled
"Auxiliary Panel"
pressurisation
bell rings.
Gasifier high temp-
erature warning.
Regenerator high
temperature warning.
Gasifier distributor
low pressure warning.
Regenerator-distributor
high pressure warning.
Regenerator low bed
level warning.
Regenerator high bed
level warning.
Gasifier high pressure
warning.
- 492 -
-------
Table F-l (Continued)
Source of Alarm
12. Experimental Burner
Failure of:
Pilot flame
Main flame
13. Fire Detector
14. Sump Level
15. Emergency Stop Buttons
in building
16. Emergency Stop Button
on panel
Auxiliary
Panel
None
Red light
and bells
Main Control Panel
Pilot flame failure
Main flame failure
Red light titled
Auxiliary panel.
Red light Nothing.
Red light
and bells
None
Red light titled
Auxiliary panel.
None
- 493 -
-------
APPENDIX G
CAFB CYCLONE EXTERNAL DRAIN SYSTEM
CAFB Cyclone Fines Return System
A major modification to the CAFB pilot plant made between
runs 4 and 5 was installation of a system for externally
draining the main gasifier cyclone legs and returning the
coarse fraction of recovered solids to the gasifier. The
system is shown in figure G-l.
Beneath each cyclone drain line is a conical receiver which
can be isolated from its cyclone by a butterfly valve A. A
line leads from the bottom of each conical vessel to a~"common
fines receiver mounted above the gasifier. A pulser
controlling valve D injects bursts of N2 into this transfer
line at a "N2 knife" location just beneath conical vessel.
Another supply of nitrogen enters each conical vessel through
valve C.
Each transfer line is isolated from the fines receiver by a
ball valve E. The fines receiver drains into the side of an
elutriator vessel fluidised by nitrogen and fitted with a
slug breaker near its top. Gas from the top of the elutriator,
together with gas from the top of the fines receiver goes to
a filter vessel in which fines are retained. The coarse
solids fraction from the bottom of the elutriator drops
through a water cooled heat exchanger to a bottom outlet from
which it falls into a pick-up line through which it is air
injected back into the gasifier. A valve in the vertical
line just above the air pickup is controlled by a differential
pressure switch to prevent flow reversal from the gasifier
toward the elutriator.
The operating sequence of valves A, C, D, and E is regulated
from a control panel in the control room. There is a separate
control panel and set of valves for each of the two gasifier
cyclones.
The controllers operate pneumatically with fluidic elements
performing all logic and time delay functions. The sequence
of operations of the controller is as follows:
- 494 -
-------
1. Valve A, is open, valves C, D and E are closed. The
vessel is filling with solids from the cyclone. A
small bleed of N2 into the body of valve A purges
the cyclone drain leg of gasifier product~gas.
2. When a timer reaches its end point, a signal closes
valve A. After a short delay to allow A to shut
completely, valve C opens to admit N2 to the vessel
to aerate and pressurise the solids in it. When
the pressure reached a suitable level, say 5 psi,
valve D begins opening and closing in rapid sequence
to inject pulses of N2 into the transfer line.
Simultaneously;, valve E opens to deliver material
to the fines receiver. Material forced from the
vessel is broken into short slugs by the action
of the N2 pulses. These slugs travel with reduced
pressure drop and with less gas consumption than
would be required for conventional pneumatic
transport.
When the vessel is empty, the pressure within falls rapidly
because there is no longer a resistance imposed by the
solids. The pressure sensor detects this fall and closes
valves C, D and E. Valve A then opens and a new filling
period begins. We expect that fill times will be of the
order of 15 minutes and emptying times about 1 minute or
less. An interlock between the two parallel systems prevents
both operating at the same time.
Solids drop from the fines receiver into the elutriator
vessel where they are cdntacted with nitrogen at about 3 ft/
sec. Fine solids are carried overhead by this gas while
coarser material falls into the downcomer wnich also is
fluidised by N2- This dowhcomer is water cooled to reduce
solids temperature enough to prevent rapid reaction with air.
Fluidising N2 for the downcomer is injected about one foot
above the bottom outlet. Nitrogen from this injector passes
both upward to fluidise the downcomer and downward to seal
against backflow of air. A restriction at the bottom of the
downcomer limits the flow rate of solids to prevent choking
the air pickup. If the height of the fluid bed in the down-
comer falls too low to provide an adequate seal against air
backflow, the pressure detector senses the reduction and
closes the bottom valve. The valve opens again when the
pressure difference is restored.
A detailed description of the operation of the fluidic
controller is given after Fig. G-l.
- 495 -
-------
Vent
Fines
Gasifier
Product
FI6.G-I QYCLONE DRAIN SYSTEM
- 496 -
-------
Description of Pneumatic Circuit
There are two parallel cyclone drain systems which empty to
a common elutriator. Each drain and transfer system is
controlled by its own pneumatic control panel. The two
systems are interlocked to prevent simultaneous transfer by
both. The controllers are based on "Fluid Log" pneumatic
elements made by Lang Pneumatic Ltd., Telford, Shropshire.
A diagram of the pneumatic circuit appears in Figure G-2
Table I compares the numbering system used in the circuit
diagram with numbers on the physical panel.
Most of the logic elements in the circuit are 5 port valves
with either pilot inlets at each end or a spring at one end
and pilot pressure at the other.
The symbols used in this memo, for these elements are as
follows:
• If an element is energised left, it means that the
left pressure is higher than right. In this case,
the element lines are as follows:
L Pressure Higher sV^S
• If an element is energised Right, the opposite applies;
— H-
R Pressure Higher
The numbers refer to the manner in which the element
parts are numbered.
The symbol used at point 2 on the above example is a
restrictive orifice. Point 3 is open to atmosphere with no
restriction. Point 5 is plugged.
Element No.3 in the diagram is a four port valve, air
operated spring loaded. With no air signal, it takes the
configuration;
- 497 -
-------
n
When air energized, it reverses to:
(p > 5 psig)
Elements 6 and 9 are two port valves, spring loaded. They
are normally closed, that is, no flow passes through them
unless pressure is applied to their pilot sides.
The oscillator consists of four elements and a regulator which
cause pulses of air to be applied to the pilot of element 9
when a signal is applied to the oscillator. Details of this
circuit are not illustrated here.
The figure illustrates the configuration of the valves when
operating air at 80 psig has been applied to all points
marked "—•", but the switch is in the "off" position.
At this point there is no pressure on either pilot side of
element 12. The position shown was maintained from the
previous operation by a "detent" feature which prevents
movement of the element when pressure is off. The element
is riormally in this position except for the brief period
during which tank pressure is building before the outlet
valve has opened.
The sequence of operations is listed in Table II and described
briefly below.
Pressure is supplied to the switch from element 12 through
element 7, but is blocked to the pilot of 10 and inlet valve
3 by the~switch. Thus the inlet is closed while the switch
Ts off.
When switch is turned on, pressure is applied to 3 to open the
inlet valve and to reverse 10 to pressurised the R-l delay
accumulator and start R-2 accumulator exhausting through an
- 498 -
-------
orifice. The exhausting of R-2 supplies the main time
delay for solids to drain from the cyclone to the transfer
tank. This time is expected to be of the order of 1O-15
minutes.
Because of the pressure applied through R-l to the pilot of
£, 2_ reverses. At this point there is still no pressure on
either side of 12, but it remains held in position by a
"detent" spring. The pilot of £ is pressurised by the air
pressure to valve A, and it reverses. Element 5^ remains
held by "detent" with no pressure on either side.
When the pressure in R-2 accumulator drops below that
supplied by "Delay-2" regulator, element _! reverses. This
starts R-l exhausting and pressurises the pilot of Ijl which
reverses. Pressure is removed from _3 pilot which reverses
to close the inlet valve.
Pressure is released from 4^ pilot which reverses in readiness
to supply pressure to the left pilot of J5.
When R-l pressure falls below that of Delay 1 regulator, 2_
reverses. This delay was provided to give inlet valve about
L5 seconds to close fully. Pressure now is supplied through
2_ to the left pilot of 12 which reverses. Pressure from 12
then goes through 4_ to reverse j5. Pressure from 12 also
reverses 1_3 to put "x" pressure on the pilot of !_• Tne
reversal of _5 applies pressure from 1JL to the pilot of 16
which opens to admit nitrogen to the transfer tank aerator.
Element 13. supplies this signal to operate its aerator so
long as the second system is not operating the other tank
aerator. If the other system is operating, the signal to
open valve j5 is delayed until transfer from the other system
is completed. Likewise, a signal from this system prevents
the second from starting if the first is aerating. The
purpose of this interlock is to prevent simultaneous high
nitrogen demand from both transfer units.
While the transfer tank is building pressure, the outlet
valve remains closed until tank pressure exceeds "x" pressure
say 5 psig. When this happens, element ]_ reverses to apply
a signal to the oscillator, to element J3, and to the right
side of 12. Element T_ removes the signal from right of 5^ and
from 10. The oscillator starts pulsing N2 through the knife
via 9. Element 8 reverses to open the outlet valve. Solids
shouTd now start~~transferring from the transfer tank to the
elutriator. The element L2 reverses to change the signal to
13 which reverses to apply "w" pressure to the right pilot
1_.
- 499 -
-------
When transfer of solids is completed, tank pressure falls
quickly. When it drops below pressure "w", element T.
reverses to restore conditions to the starting pointT Signal
is removed from the oscillator, from Br and from the right
side of 12. The oscillator stops pulsing the knife through
9 and element 8^ reverses to close the outlet valve. Pressure
Ts applied through T_ to j> which reverses to stop the N2
flow to the aerator, and signal is applied to 1O and to 3^
which reverses to open the inlet valve. Reversal of 10
starts the long time delay exhausting of R-2 and
repressurises R-l to reverse element £. The transfer tank
is now again receiving solids from the cyclone.
- 500 -
-------
Table G-l
Composition of Element Numbering System
Number of Fig.l
1
2
3
4
5
6
7
8
9
10
11
12
13
14
Number on Panel
17
18
-{on front)
9
11
-{in pit)
13
15
-{in pit)
16
int
7
12
behind panel
Catalogue No.
PLV 52/16F/B
PLV 52/16F/B
PLV 52/15H/B
PLV 52/15D/B
PLV 52/16F/B
PLV 52/15H/B
PLV 52/15H/B
PLV 52/15H/B
PLV 52/16D/B
PLV 52/16F/B
PLV 52/15H/B
- 501 -
-------
Table G-2
01
o
Supply On
Switch
Valve
R-l P
R-2 P
W
X
Inlet
Outlet
Aerator
Knife
Tank P
1
2
3
4
5
6
7
8
9
1O
11
12
13
14
O
OFF (1)
L
R (3)
L (2)
R (3)
R
R
R
R
R
L (2)
R
R
L
L
8O
80
1 PSI
5 PSI
Closed
Closed
Off
Off
o
Sequence of Controller Operations
Turn on Switch R.2 < Delay 2 P R-l P < Delay 1 P Tank R > X Powder Empties Repeats
8 min 1O sec Tank P < W Cycle
* ON
L (1)
* L
* R (3)
* L short (4)
delay
R
R
R
R
R
* R
R
R
L
L (2)
80
Exhausting >
1
5
* Open
Closed
Off
Off
O
ON
* R
L
* L
* R - short
delay
R
R
R
R
R
R
R
R
L
* R
Exhausting >
< Delay 2
* Closed
Closed
Off
Off
0
(4)
(1)
(3)
(4)
(3)
(2)
(3)
(5)
ON
* L
* R
L
R
* L
* L
R (1)
R (2)
R (2)
* L
R
* L (2)
* R (3)
* L
> O
— > 80
1
5
Closed
Closed
* On
Off
Rising < X
ON
L
R
L
R
L
L
* L
* L
ON
L
(3)
(2)
(3)
(2)
(3)
(1)
(2)
* Pulsing (2)
L
R
* R
* L
L
0
8O
1
5
Closed
* Open
On
* On
Steady
(2)
L
R
L short delay
R
R
R
R
R
R
R
R
L
L
80
Exhausting > Delay 2 P
1
5
* Open
* Closed
* Off
* Off
0 < W
* indicates a change
(1) number in parentheses indicates order of event
-------
Aerator
on Tank
Ul
O
Inlet Valve
< - A
Open Close
Knife
Outlet Valve
FIG. G-2 CIRCUIT OF CYCLONE FINES PUMP CONTROLLER
-------
APPENDIX H
GAS ANALYSIS
BATCH UNITS
The gas analysis equipment used in the batch units is the same
as used in Phase I, and is listed in Table 1.
Appendix H - Table 1
Batch Unit Gas
Analysis Equipment
Analyser Type Manufacturer Model Response Range
S02 Infra-red Maihak Unor 6 Continuous 0-1,000 ppm
S02 Infra-red Maihak Unor 6 " O-20% by vol.
S02
CO2
CO
02
Conducti-
metric
Infra-red
Infra-red
Para-
magnetic
Wostoff
Maihak Unor 6
Maihak Unor 6
Servomex OA 137
0-10OO ppm
O-20% by vol.
O-20% by vol.
0-25% by vol.
During fully combusting conditions and also regeneration of
sulphide, the gas from the reactor is pulled through a water
condenser and filter and monitored directly for CO2, CO, 02,
and S02. The appropriate information on combustion efficiency,
sulphur removal efficiency or sulphur release is then deduced.
During gasification, a portion of the product gas is burned in
a sample flame located just above the reactor and the combustion
products analysed for SO2, O2t CO and C02. The desulphurising
efficiency of the gasifier is calculated from this analysis of
the fully combusted gas. Because of the wide range of sulphur
compounds present in the gasifier product itself, this is the
only practical method for measuring gasifier sulphur removal
efficiency. During this operation no in-line filter is used.
Efficient cyclone operation and counterflow sampling are
relied upon to separate particulates from the gas stream.
This system has been shown to provide a representative sample
- 504 -
-------
of combusted gas and consequently, a reliable measure of SRE.
It has been tested by passing sample gases containing the
appropriate amounts of SO2 through it and sulphur balances
have been obtained.
CONTINUOUS PILOT PLANT
The gas analysers used during continuous pilot plant operation
are the same as used, in Phase I and are listed in Table II
along with their applications.
Appendix H - Table II
CAFB Pilot Plant Gas Analysers
Gas Stream
Air-Flue Gas
Mix to Gasifier
Plenum
Boiler Flue
Gas
Sampled at fire
tube outlet
Component
02
C02
02
C02
CO
S02
S02
Analyser
Servomex
OP 25O
Maihak
Unor 6
Servomex
OA 137
Maihak
Unor 6
Maihak
Unor 6
Maihak
Unor 6
Wostoff
Operating
Principle
Paramagnetic
Infra-Red
Paramagnetic
Infra-Red
Infra-Red
Infra-Red
Electrical
Regenerator
* Variable Range.
C02
S02
C02
Range
O-25% by vol
O-1O% by vol
O-5% by vol
0-2O% by vol
O-2O% by vol
O-1OOO ppm
0-1OOO ppm
conductivity
of H2O2 - SO2
reactor
products in
solution
Servomex
OA 137
Maihak
Unor 6
Maihak
Unor 6
Pye
Paramagnetic
Infra-Red
Infra-Red
0-2.5% by vol
0-10% by vol
O-20% by vol
Gas Chromato- 0-100% by vol*
S02 ) Series 104 graphy
- 505 -
-------
With the exception of the gas chromatograph , all the analysers
give a continuous response.
Figure H-l is a flow diagram for the pilot plant gas analysing
equipment as used in Runs 4 and 5. The boiler gas sample was
drawn through a hole in the refractory brickwork in the
centre of the boiler rear door. This point was selected to
provide a sample stream immediately after combustion in
the main fire tube and before the gases passed through the
water tubes where lime not trapped by the gasifier cyclones
might be expected to deposit and might absorb some of the SC>2
in the gas stream. The regenerator gas sample was drawn
from a point immediately after the regenerator cyclone where
it was expected to be relatively free of solids.
During many of the test periods in Run 5, a poor sulphur
balance was obtained. It was recognised that one
possible reason for this could have been loss of SO2 in the
boiler sampling system. Lime was indeed observed to build
up quite rapidly in the sampling line during Run 5 due both
to poor gasifier cyclone efficiency and to the relatively
high attrition rate of BCR 1691 limestone which was used for
part of the run. To counteract this, therefore, the sampling
system was modified before Run 6. The new arrangement
incorporated a much larger gas stream through the sampling
point in the boiler door which then passed through a cyclone
before venting to atmosphere. The small sampling stream was
taken from the cyclone outlet and passed through a filter,
a water separator and then to the gas analysers as before.
This design ensured that most of the dust was removed from
the sample stream and did not obstruct the filter and
possibly absorb
The Run 6 gas analysis showed a generally higher level of
SO? in the boiler than Run 5 and hence lower sulphur removal
efficiency. The sulphur balance during Run 6 was closed
within experimental error.
During Run 7, the boiler sampling system was investigated
further. The results of the tests are recorded in the log
of Run 7 in Appendix D. It has been concluded that a low
sampling flow rate through the boiler brickwork in the
presence of hot lime will not give accurate results because
of absorption of SO2 on the lime. A high volume sample
stream achieves two improvements in that the residence time
in the hot brickwork is considerably reduced and the
increased velocity minimises the deposition of material in
the duct which still needed regular cleaning during operation
- 506 -
-------
to eliminate errors due to reabsorption. Sulphur balance
was also closed in Run 7.
It would appear, therefore, that the problems in accurately
measuring S02 in the combusted gas from the continuous pilot
plant which were not evident in operating the batch reactors
were due primarily to the relatively low efficiency of the
gasifier cyclones. The consequent higher solids loading in
the boiler gas and the positioning and operation of the
sampling point then combined to produce unreliable SO2
measurements unless the sampling system was cleaned very
frequently.
- 507 -
-------
CAFB PILOT PLANT
FLOW DIAGRAM FOR GAS ANALYSING EQUIPMENTtRUNS 4AND5)
To Outside
O
oo
Bubbler
Rotometer
Separator
Condenser
Condenser
Filter
Filter
BOILER
PLENUM
AIR LINE
To Outside
Bubbler
Pump Condenser
Filter
, REGENERATOR
Figure H-l
-------
APPENDIX I
GASIFIER HEAT BALANCE
A heat balance around the regenerator has been used to
calculate the stone circulation rate. This balance and the
consequent computer programme has been reported in the Final
Report of Phase I of this work (Reference 1). This
programme was used to calculate the stone circulation rate
from data for Run 5, which values are reproduced in Appendix
B of this report. An improved programme, which allows for
the internal recycle of solids from the right hand cyclone,
allows for solids drained from the regenerator and lost as
fines, uses improved enthalpy data and an improved heat loss
calculation, is in the process of being developed as a part
of the mathematical model studies in Phase III.
The gasifier heat balance programme presented in the Interim
Report of Phase II of this work is reproduced here together
with outputs calculated from Run 5 data. This programme is
being extensively modified and expanded as a part of the
mathematical model studies of Phase III of this work, and
will be converted to metric (S.I.) units.
The heat released in the gasifier under partial oxidation
conditions depends on the air fuel ratio and on the relative
extents of the various competing reactions within the bed.
As a first step in development of a mathematical model to
predict gasifier operating conditions, a series of heat and
material balance equations have been programmed to compute
the heat release rate in the gasifier from measured flow
rates and temperatures. A second set of equations is used
to estimate the heat release rate from heats of reaction and
from estimates of the relative amounts of hydrogen and carbon
oxidised and the CO/CO2 ratio produced.
List of Variable Names
Variable Meaning Units
F Fuel Rate Ib/Hr
A Air rate SCFM
D Gasifier bed depth inches
S Average bed particle size microns
STNRT Fresh stone feed rate Ib/Hr
TC Gasifier bed temp. Deg.C
TR Regenerator bed temp. Deg.C
- 509 -
-------
Variable Meaning
V Superficial gas velocity
CPCT Carbon in fuel oil
HPCT Hydrogen in fuel oil
SPCT Sulphur in fuel oil
CAOPCT CaO in stone
02INFG Oxygen in flue gas
STNCIR Lime circulation rate
G Flue gas inlet rate
CO2FG Carbon dioxide in flue gas
TAIN Temperature of inlet plenum
O2FED Oxygen feed to gasifier
RATIO CO/CO2 ratio produced in
gasifier bed combustion
FRC02 Fraction of C02 in CO and
CO2 produced in gasifier
bed combustion
TG Gasifier temperature
HCC02 Heat of Combustion for C
to C02
HCCO Heat of combustion for C
to CO
HH2H2O Heat of combustion for H2
to H20
ST02 Oxygen needed for stoichio-
metric combustion of
fuel oil
R Oxygen fed as percent of
stoichiometric
TRF Regenerator temperature
BTUCIR Heat transferred from
regenerator to gasifier
by circulating lime
BTUOIL Heat required to raise
temperature of oil from
inlet to gasifier
temperature
BTUCRK Heat required to crack oil
to H2 + C
BHA Heat required to raise
inlet air from plenum
temperature to 16OO
Deg. F.
BTUAIR Heat required to raise inlet
air from plenum temperature
to gasifier temperature
C Ratio of CaO to S fed
Units
ft/sec
wt.%
wt.%
wt.%
wt.%
Vol.%
Ib/Hr
SCFM
Vol.%
Deg.F
Ib Mole/hr
Dimensionless
Dimensionless
Deg. F
Btu/lb mole C
Btu/lb mole C
Btu/lb mole H2
Ib Mole O2/100 Ib oil
percent
Deg.F
Btu/Hr
Btu/Hr
Btu/Hr
Btu/Hr-CFM
Btu/Hr
Dimensionless
- 510 -
-------
Variable Meaning
BTUCAL Heat required to calcine
limestone
BTUCO2 Heat required to raise
temperature of CC>2 from
limestone to gasifier
temperature
BTUSTN Heat required to raise
nonvolatile part of lime-
stone to gasifier temp.
BTULOS Heat lost from gasifier bed
through walls
BTUFXD Net heat input to gasifier
except for reaction and
flue gas contributions
AA Constant in equation for
percent of carbon oxidised
COXDP Portion of fuel carbon
oxidised
COXDM Amount of fuel carbon
oxidised
BTUCC02 Heat released by oxidising
carbon to CC>2
BTUCCO Heat released by oxidising
carbon to CO
BTUH2O Heat released by oxidising
hydrogen to H2O
BTUFG Heat required to raise flue
gas from plenum to gasifier
temperature
BTUBRN Heat released by combustion
in gasifier
HTREL BTUBRN X 10~6
BTULB Heat released per Ib oil
by combustion in gasifier
HOXD Heat released per mole
oxygen by combustion in
gasifier
HOXDM Amount of fuel hydrogen
oxidised in gasifier
HOXDP Portion of fuel carbon
oxidised
HOXDM and HOXDP are based
on heat balance calculation
C02M Amount of fuel carbon
oxidised to C02
Units
Btu/Hr
Btu/Hr
Btu/Hr
Btu/Hr
Btu/Hr
Dimensionless
Percent
Ib Mole/lOO Ib fuel
Btu/lOO Ib fuel
Btu/lOO Ib fuel
Btu/lOO Ib fuel
Btu/Hr
Btu/Hr
(Btu/Hr) x 1O~6
Btu/lb oil
Btu/lb mole
Ib Mole/lOO Ib fuel
Percent
Ib Mole/lOO Ib fuel
- 511 -
-------
Variable
COM
02H2O
HOXDM2
HOXDP2
HDFL
Meaning
Amount of fuel carbon
oxidised to CO
Amount of oxygen converted
to H20
Amount of fuel hydrogen
oxidised
Portion of fuel hydrogen
oxidised
HOXDM2 and HOXDP2 are based
on material balance
calculation
Heat release per mole
oxygen by combustion in
gasifier, calculated by
stoichiometry and reaction
heats
Units
Ib Mole/100 Ib fuel
Ib Mole/100 Ib fuel
Ib Mole/100 Ib fuel
Percent
Btu/lb mole
Thermal Equations
The thermal equations are linearised forms which adjust for
departure from tabulated values at 16 OO Deg.F.
HCC02 = 169790 + .434 * (TG-1600)
HCCO = 48525 + .7375 * (TG-16OO)
HH2H20 - 106941 + 1.327 * (TG-16OO)
The air heat equations are based on published enthalpies at
100°F and 1600*F and on specific heats (Cp) at these levels.
BHA =
(H160° - (H10°
BHA = Enthalpy change to heat air from inlet temp, to 16OO°F
The term 60 converts from CFM to Ib Mole/Hr
150
BHA = .1579* (15057 -(3825 + 6.98* (TAIN-10O.) ) )
BTUAIR - A *(BHA + !|§Q *Cpl60o} * (TG-1600))
BTUAIR = A *(BHA + .O439 *(TG-16OO)
The enthalpy change to heat the flue gas is based on a flue
gas of assumed composition:
- 512 -
-------
2.44% 02; 75% N2; 10.1% H2O; 12.5%
Weighted average values of enthalpies and specific heats
were combined to obtain the final equation.
BTUFG = G ** (H160Q - H30Q + Cpl6QO * (TG-1600)
+ Cp300 (300-TAIN))
BTUFG = G *.1579 * (10719 + 8.902*TG - 14343 - 7.423*TAIN
+ 2227)
BTUFG = G * (1.4056 * TG - 1.172*TAIN - 2O4.79)
Heat of limestone calcination is taken at 1410 Btu/lb of CaO
BTUCAL = STNRT * CAOPCT * .01 x 1410
BTUCAL = STNRT * CAOPCT * 14. 1O
Heat to raise temperature of C02 liberated in calcination.
BTUC02 = STNRT * CAOPCT * j- * (H1600 + C 16OQ (TG-16OO) )
BTUC02 = STNRT * CAOPCT * j~ * (17935 + 13.36 (TG-1600)
BTUC02 - STNRT * CAOPCT * (3.203 + .OO239 * (TG-16OO) )
Heat to raise temperature of nonvolatile portion of stone.
BTUSTN = (STNRT) * (Fraction Nonvolatile) * (H16QO
+ Cpl600* (TG-1600) )
BTUSTN = STNRT * (1 - CAT *(362.9 + .284 * (TG-16OO) )
BTUSTN = STNRT * (1 - .O0786 * CAOPCT) * (362.9
+.284* (TG-1600))
Heat supplied to oil.
Heat uptake by the oil is made up of sensible heat, latent
heat, and heat of cracking.
Sensible heat and latent heat are included in a linear
equation based on the oil enthalpy at 12OO*F and the specific
heat of the oil between 1200 °F and gasifier temperature.
- 513 -
-------
BTUOIL = F * (780. + 0.84 * (TG-12OO))
The heat of cracking is assumed to be 60O Btu/lb
BTUCRK = F * 6OO
The heat loss from the gasifier bed is estimated from an
analysis which indicated that the effective product of
thermal conductivity and bed area is equal to 0.242 x D.
The heat loss equation is therefore:
BTULOS = O.242 * D * (TG-7O)
Material Balance Equations
Oxygen fed.
02FED = 0.21 * 6Q * A . 6O * r * 02INFG
380 A 380 u 100
02FED = .0332 * A + .OO158 * G * 02INFG
CO/C02 Ratio
The ratio of CO to C02 produced by partial combustion of oil
in the fluid bed is a complex function of themodynamics,
reaction kinetics, and contacting in the bed.
Analytical results indicate that the values obtained are
much lower than equilibrium for the temperatures encountered.
It is believed that considerable C02 forms by reaction of
carbon on lime in the highly oxidising region near the air
inlet nozzles and that insufficient contacting time is
available for this CX>2 to reach equilibrium with CO and carbon
in the upper portion of the bed.
The equation used here is an empiricial equation relating
CO/C02 ratio to temperature, based on gas analysis data
obtained in the batch CAFB reactors during the phase I study
and reported in Appendix D of reference (1). The equation
is:
RATIO = 2.91 E-4 * EXP{9.76 E-3 * TC)
- 514 -
-------
Fraction of Carbon Oxidised
In the current analysis it is assumed that components of the
flue gas , recycled for temperature control , do not react in
the gasifier. The validity of this assumption remains to be
verified. With this assumption, fixing the CO/C02 ratio and
the fraction of feed carbon oxidised also fixes the fraction
of feed hydrogen oxidised since the oxygen fed must appear
as CO, CC>2 or
The fraction of carbon oxidised is based on an empirical
equation first derived from batch unit studies but modified
to improve match with the heat results of the continuous
pilot plant runs. This equation is:
COXDP = EXP(-AA) * (R t.942) * (TC 4- 1.336)
A value of 8.4 for (AA) has given the best match between
measured and calculated heat release rates.
The moles of carbon oxidised per 1OO Ib of fuel is the
product of the fuel carbon content and fraction oxidised.
COXDM = 1_* CPCT# COXDP
12 100
COXDM - 8.333 E-4 * CPCT * COXDP
Calculated Heat Release of Fuel Oil
The calculated heat release per 1OO pounds of fuel is given,
for each element, by the moles of that element oxidised
multiplied by the heat of combustion of that element.
BTUCC02 = HCC02 * COXDM * FRCO2
BTUCCO = HCCO * COXDM * (1 - FRCO2)
BTUH20 - HH2H20 * HOXDM
The total heat release is the sum of that for the elements.
"Measured" Heat Release
The "measured" heat release is the difference between the
sensible heat inputs to the gasifier and the heat required
to raise the products to gasifier temperature.
- 515 -
-------
BTUBRN = BTUFG + BTULOS + BTUCAL -4- BTUOIL + BTUCRK + BTUAIR
+ BTUSTN + BTUCO2 - BTUCIR
Hydrogen Oxidised
The amount of hydrogen oxidised can be estimated from the
heat balance or from the oxygen balance.
Derivation of the heat balance equation for HOXDM is as
follows:
„ . . „ __••_ rt _ Heat of Combustion of elements
Heat release per mole 02 Q2 needed to burn elements
u^Vo BTUCCO2 + BTUCCO + BTUH2O
nUXD = i j
175^ (HOXDM + COXDM * (1 + FRC02) ))
Also from the measured heat release in the gasifier,
HOXD * BTUBRN/02FED
Substituting, BTUH20 = HOXDM * HH2H20
gives,
BTJUCC02. + BTUCCO + HH2H2O * HOXDM
{.5 * (HOXDM + COXDM * (1+FRC02)))
Rearranging and solving for HOXDM gives:
HOXDM = (BTUCC02 + BTUCCO - (.5*COXDM * (1. + FRC02))*HOXD)/
(,5*HOXD-HH2H20)
Material balance hydrogen oxidised
Since all oxygen fed to the gasifier is assumed to make CO,
CO-, or H2O, fixing the amounts of CO and C02 by empirical
expressions also fixes the quantity of H20.
C02M = COXDM * FRC02
COM = COXDM - C02M
02H20 = 02FED * 100/F - C02M - COM/2
HOXDM2 = 02H20 * 2
Calculated Heat Release per Mole 02
A purely calculated heat release per mole oxygen can be
computed for comparison with the "measured11 value. For this
purpose a value of BTUH2O is calculated using the material
balance value of hydrogen oxidised.
- 516 -
-------
BTUH20 = HOXDM2 * HH2H20
then,
HDEL = .01 * F * (BTUCC02 + BTUCCO + BTUH2O)/O2FED
These heat and material balance equations have been used in
several computer programs to analyse experimental data and
to predict new operating conditions. Table 1-1 lists the
Fortran statements of programme JHTHOC which calculates the
gasifier heat release from experimental operating conditions
and compares the value with the predicted value. Results
of calculations on CAFB data appear in Table I-II.
- 517 -
-------
APPENDIX I Table 1
FORTRAN LISTING OF CAFB HEAT BALANCE PROGRAMME
JHTHOC
I00C CALCULATE HEAT OF COMBUSTION FROM CAFB CONDITIONS
110C PROGRAM NAME JHTHOC
120 PRINT 600
130 DIMENSION P<25)
140 SFILE JHTFI1
150 50 CONTINUE
160 READ Cl) (PCI)* 1=1.17)
170 IF CENDFILE 1) 10* 800
180 10 CONTINUE
190C DEFINE VARIABLE VALUES
200 100 F = PC|) 'FUEL RATE* LB/HR
210 A = PC2)
220 D = PC 3>
230 S = P<4> 'AVERAGE PARTICLE SIZE. MICRONS
240 STNRT = PCS)
250 TC = PC6) 'GASIFIER TEMP DEC C
260 TR = PC 7) 'REGENERATOR TEMP DEC C
270 V = PCS) 'GAS VELOCITY (INITIAL ASSUMPTION)
280 CPCT = PC 9) 'CARBON IN FUEL* WT. PCT
290 HPCT = P<10) 'HYDROGEN IN FUEL* WT. PCT
300 SPCT = P<1|) 'SULFUR IN FUEL* WT. PCT
310 CAOPCT * PC 12) "CAO IN STONE* WT. PCT
320 02INFG = PC 13) '02 IN FLUE GAS* VOL PCT
330 STNCIR = PC 14) 'LIME CIRCULATION RATE* LB/HR
340 G = PC 15)
350 C02FG = PC 16)
360 TAIN = PC17)*|.8+32» 'AIR INLET TEMP* DEC F.
370 TG = 1 .8*TC * 32.
380 TRF = 1.8*TR*32.
390 BTUCIR = STNCIR*CTRF-TG)*.284 'MEAT SUPPLIED BY CIRCULATING LIME
400 BTUOIL = F*C780. + .84*
410 BTUCRK » F*600. ' HEAT TO CRACK OIL
420 BHA = .1579*C15B57.-<3825.*6.98*
480 BTULOS = * 242*0* CTG-7*1.)
490 BTUFXD = BTUCIR-BTULOS-BTUCAL-8TUOIL-8TUCRK-BTUAIR-BTUSTN-BTUC02
500 BTUFG = (1.4056*TG-1.172*TAIN-204.79)*G
510 BTUBRN » BTUFG-BTUFXD
520 HTREL = BTUBRN/1.E*06
530 BTULB * BTUBRN/F
540 02FED * .0332*A*.0«I58*G»02INFG 'MOLES 08 TO GASIF1ER/HR
550 HOXD =• BTUBRN/02FED
560 150 RATIO * 2.91E-4*EXPC9. 76E-3*TO
570 FRC02 = L/C RATIO * !•> 'FRACTION C02 IN PRODUCT GAS
580 ST02 = CPCT/12. *HPCT/4. * SPCT/32. 'STOIC 02* MOL/180 L§
590 R = 1.E4*OeFED/
-------
APPENDIX I Table I
FORTRAN LISTING OF CAFB HEAT BALANCE PROGRAMME
JHTHOC CONTINUED
600 AA a 8*4
610 200 COXDP * EXP(-AA>** C TO CO
650 HH2H20 = 106941. * 1.327-KTG-1600.> ' REACT HEAT* H2 TO H20
660 BTUCC02 * HCC02*COXDM*FRC02 'BTU/100 LB FUEL FOR C TO CO?
670 BTUCCO = HCCO*COXDM*<1.-FRC02)
680 HOXDM= )*HOXD) /( . 5*HOXD-HHf>H20>
690 HOXDP = 2.E2*HOXDM/HPCT
700 C02M = COXDM*FRC02
710 COM = COXDM-C02M
720 02H20 « 02FED*100./F -C02M-COM/2.
730 HOXDM2 = 02H20*2.
740 HOXDP2 = HOXDM2/
750 BTUH20 = HOXDM2*HH2H20
760 HDEL = .0I*F*(BTUCC02*BTUCCO*BTUH20)/02FED
765 PRINT *HOXDP*HOXDP2
700 610 FORMAT < 4X» F5. 1 » 4X» F6.2. 4X» F7.0* 4X* F8 .0» 4X. F7.0» 4X« F5. I )
790 GO TO 50
800 600 FORMAT
-------
APPENDIX I TABLE II
Gaslfier Thermal Performance
Run Time
Pay-Hour
1,2130
10,0030
3,0050
3,1330
•4,0430
'^,0530
7,1130
8,2300
8,1130
10,1330
2,1230
5,0630
6,0430
7,0330
1,0930
1,1030
2,0030
2,0830
2,1130
3,0230
3.0630
•5,0730
3,0830
3,1130
7,0830
7,0930
7,2150
7,2230
7,2330
8,1230
8,2330
9.0730
9,0830
9,1130
9,1830
9,2330
10,0230
10,1430
10,1530
^,1330
4,1530
8,0630
7,1530
2,0030 *
2,0430 *
6
.9
.6
I
.7
.0
II
II
7
6
12
13
16
15
14.3
18.6
39.6
36.5
40.9
17.0
26>8
24.8
19.7
19.4
15.5
24.6
20.0
11.1
12.5
18.8
21.8
34.0
86.5
-.9
2.2
- 520 -
-------
APPENDIX I TABLE II
Thermal Performance
en
to
Run Time
Day-Hour
2,21)0
3,0550
5,1550
5,2150
5,1050
6,0750
12,1550
12,1950
15,0550
12,0850
17,1250
17,1750
21,0950
21,1850
22,0750
22,1850
24,0750
25,0550
25,1550
26,0550
26,1850
15,0650
26,1150
(
"inmnuted by Programme
Heat
Total
Btu x 10b
• Z6
.23
• 26
.29
• 31
.24
.23
.20
.26
.26
.25
.28
.39
• 40
• 27
.26
.29
• 27
.25
.25
.25
• 26
1.24
Run 5
Release In
Per Ib Oil
HT.ii
3173.
3102*
3198.
3195.
3277.
3237.
3105*
3026.
3216*
3165.
3129.
3187.
2968.
2977.
3066.
3079.
3146.
3131.
3085.
3048.
3046.
3226.
3024.
dHTHOC
Gasifler
Btu/lb Mole
Measured
159492.
151492.
154496.
156095.
152803*
157959.
149565.
145809.
154398.
152395.
145675.
144341 •
149845.
155948.
155877.
154165.
1 629 69 .
1 62098 •
160530*
160349.
161566.
153912.
166220.
02
Model
152692.
1 52409 •
152704.
151379.
1 56889 •
156234.
154505.
154375.
154770.
153613*
155509.
155854.
150096.
151771.
153294.
153987.
155273.
153230.
153597.
152916.
153916.
153772.
154561 •
Percent Hg Oxidised
Mass
Balance
14.0
14*5
14.7
14*6
15.1
14.3
14.6
14.6
14.6
14.7
15*2
15.7
14.1
13*3
13.
13-
13.
13.
13.
,7
.9
.3
.4
• 3
13.2
13*0
14.8
12.4
Heat
Balance
22*6
13*4
.16.8
20.4
10.0
16*4
9.0
5.4
14.1
13*2
4-3
2.8
13.7
18.1
16.8
14.1
23-5
25.0
22.0
22.4
22.6
15.0
28.0
-------
APPENDIX J
ANALYSIS AND ESTIMATION OF ERRORS
A thorough analysis of the probable errors associated with
data used in the calculation of sulphur removal efficiency,
overall sulphur balance and regeneration selectivity as well
as errors associated with a carbon, hydrogen and oxygen
balance around the gasifier and regenerator unit has been
carried out as a preparatory step to using our data for the
development of a mathematical model in Phase III.
An illustration of the approach used in the error analysis
is given here, based on data from the early part of Run 6
(at day time 6.190O) at which time two simultaneous gasifier
product gas samples were taken. Any equations used in data
conversion are in the listing of programme ZKDAT, in Appendix
K.
1. Calculation of Regenerator Errors
The streams entering and leaving the regenerator, and subject
to error are:
Input
Regenerator air (total flow meter and stop watch)
Nitrogen to solids transfer (total flow meter and stop
watch, some slip).
Output
Analysis of regenerator product gas for S02, (X>2 and Q£
(analysers).
Solids drained from the regenerator (weighed).
Interpolated values
Solids drained from regenerator cyclone (weighed).
Analysis of solids drained from regenerator cyclone,
regenerator and gasifier (chemical analysis of samples
for S, S04 sulphur and C).
Unmeasured values
Regenerator product gas flow rate.
Stone transfer from gasifier to the regenerator.
Stone transfer from regenerator to gasifier.
Internal stone recycle from right hand cyclone.
- 522 -
-------
Errors
Regenerator air + 1% (estimated)
Nitrogen to solids: although most of the gas flows in
the direction .of the solids/ there is some flow the
other way introducing an error (estimated from likely
maximum and minimum flow resistance) of + 2O% .
Regenerator product gas
SO? ; scale reads 1O to 1OO, corresponding to
0-2O% S02. The scale is read to the nearest 1
(mean error O.5) division, calibration contributes
another 0*5 of a division, swings of the needle
(based on 12 successive readings at 15 sec intervals)
gave a standard deviation of 0.5 i.e. a 95%
confidence limit of 1 division.
Total reading error *= (O.52 + O.52 + I2) ^
= 1.2 divisions.
Manufacturer's tolerance on calibration gas + 5%
of the SO2 concentration, supplied in 5% and 1O%
concentrations .
At 5% the reading is 33, reading error =
- 5'2%
Total % error = (5.22 + 52)^ = 7.2%
7.2% of 5% concentration = O.36%
\
Therefore at a meter reading of 33 the 803 =
5 + 0.36%. With 10% calibration gas the meter
reading is 56.
Reading error = /J x 1OO = 2.6%
Total % error = (2.62 + 52)* = 5.6%
5.6% of 10% concentration = 0.56%
Therefore at a meter reading of 56 the SO2 =
10 + 0.56%
- 523 -
-------
Assuming linear variation of error with SO2
concentration, we have
Absolute error of regenerator SO?; concentration
= 0.04 x %SO;> + 0.16
CO?: Similar analysis to above yielded scale
readings + O.5, oscillations + 2.
Total reading error = (O.52 + O.52 + 22)
=2.1 divisions.
5% CO2 gave a reading of 66, reading error = 3.8%
Total error = (3.82 + 52)^ = 6.3%
Absolute error at 5% C02 = O.32%
1O% CO2 gave a reading of 96, reading error =2.4%
Total error = 2.42 + 52)^ = 5.5%
Absolute error = O.55%
Absolute error of regenerator COa concentration
= O.O46 x %C02 + O.O9
£2: needle can be read to + O.I, calibration gas
errors are negligible (pure~~nitrogen and air and
no oscillations observed therefore manufacturer's
tolerance of + O.2% absolute error accepted.
t
H20: concentrations observed by gas chromatographic
measurements corresponded to a carbon composition
of approximately CHo.5- l^O was therefore calculated
as O.25 x measured C02 and the error of this estimate
is a combination of the error associated with the
(X>2 measurement combined with the error in the
assumed composition for the reaction
CHn + 02 •*• C02 + | H20
a tolerance of + 0.2 on n = O.5 corresponds to a
percentage error of 4O% which is unlikely to be
optimistic and also completely swamps any
contribution from the C02 measurement.
Therefore H20 concentration = O.25 x CO2 x (1 + o.4)
- 524 -
-------
N2 : obtained by difference:
N2 = 10O - 02 - S02 - 1.25 C02
Absolute error of N2 = (sum of squared absolute
errors of 02, S02 and H2O)^.
Regenerator gas flow was calculated by nitrogen
balance:
0.79 x Air + Reg.N2 = Regen. gas flow x N2 concentration
The errors are combined in the usual way by summing
sqaured absolute errors for added or substracted
quantities and by summing squared percentage or
fractional error for multiplication or division.
The above estimates are illustrated by the following example
which illustrates the measurement errors and calculation of
regeneration selectivity.
2. Example of Regenerator Measurement Errors - Regenerator
Selectivity
Run 6, 6.19 Day time, averages of Day time 6.183O and 6.1930
used.
Regenerator air = 33.75 m3/h, 1% error = 0.34 m /h.
" N2 = 1.1 " , 20% error = O.22 m3/h.
Therefore: O2 in = .21 x 33.75 = 7.O88 m3/h,
error = .21 x .34 = O.O71 m3/h.
N2 in = .79 x 33.75 + 1.1 = 27.76 m3/h
error = ((.79 x .34)2 + .222)^
= 0.35 m3/h
Regenerator S02 = 7.4 + (O.O4 x 7.4 + .16) = 7.4 + 0.46%
Regenerator CO2 = 4.2 + (O.046 x 4.2 + O.09) = 4.2 +
0.28%
Regenerator 02 = 0.5 +0.2%
Regenerator H2O = 0.25 x 4.2 (1 + O.4) = 1.O5 + O.42%
Regenerator nitrogen = 1OO - 7.4 - 4.2 - O.5 - 1.O5 =
86.85%
error = (0.462 + 0.282 + O.22 + 0.422)15 = + 0.71%
Therefore: N2 = 86.85 + 0.71%
- 525 -
-------
Let regenerator product gas flow = Q m^/h/ then:
27.76 = Q 8?A^5 / Q = 31.96
2 2
fractional error = {|fj3fyj + 2
mols CaS oxidised to S02 = Q x
_ 31.96 x 7.4 _ n
-- 2271.1 " 0'
fractional error = { [g * + <>2 = O.O64
absolute error = 0.064 x 0.1041 - O.O067
therefore: CaS oxidised to SO2 = 0.1O41 + O.OO67 kmols/h
Oxygen not used for above and for oxidation of CH
is used to make sulphate: 5
CaS + 2 02 -*• CaSO4
mols 02 accounted for = Q *1.5 x y^ + -^— + __2
\ ±uu xuu xuu +
. J X 1 /•>/•>< X n r» •
100) " 22.711
•6
(1.5 x 7.4 + 0.5 + 4.2 +
0.5 x 1.05)
x 16.325 = 0.2397
2 2
Error of concentration term = ((1.5 x .46)* + .2 + .;
+ .42^)^ = 0.88
fractional error = { {jjf^ |+ {g^}} - O.O559
- 526 -
-------
absolute error = 0.0559 x 0.2397 = O.013
therefore: O2 accounted for = O.2397 + 0.013 kmols/hr;
" : 02 used to make sulphate = 22°711 ~ °'2397
= O.O724 kmols/hr
2
error = {{^mj + O.O132^ = O.O134 kmols/hr
therefore: Mols CaSO4 made = O.O362 + O.OO67 kmols/hr
(since 2 mols O2 are required to make 1 mol
of CaS04)
Selectivitv = mols CaS to Cap x 1OQ _
y rtiols CaS to CaO + mols CaS to CaSO4
= 0.1041 x 100 - IA >>
0.1041 + 0.0362 - '*"*
- no.0067)2 .00672 + .00672)^
((0.1041) .1041 + .0362 }
fractional error
= O.0691
absolute error = 0.0691 x 73.5 = 5.1
therefore Selectivity = 74.2 ± 5.1%
Similar calculations for different conditions, which yielded
selectivities in the range 50 - 1OO%, indicate that the error
remains fairly constant at about 7% of the actual value.
The estimation and associated errors of the stone transfer
will be considered under balances, later on in this report.
3. Calculation of Gasifier Errors
Gasifier air; the main air flow is measured by a
calibrated inlet orifice in cfm. The air added with
stone feed is measured by a rotometer; the injector and
burner purge air are recorded as a sum of 4 rotometer
readings. All the rotometer readings are corrected for
pressure and temperature and can be taken as correct to
+ 7%.
The orifice pressure drop is read to the nearest 5 cfm
with the following cumulative errors:
- 527 -
-------
reading round-off = 1.25 cfm
fluctuations = 2 cfra
orifice tolerance +1% = 2.5 cfm (on a reading of 25O)
calibration +1% =2.5 cfm (on a reading of 250)
total =4.25 cfm = 6.9 m3/hr.
Air with stone feed, 7% on 8.6 m3/hr =0.6 m3/hr
Injector and burner purge/ 4 readings of about 6.8 m3/hr
error = (4 x (.07 x 6.8)2)*s = i.o m3/hr.
Total error on gasifier air = (6.92 + O.62 +1.O) ^
= + 7.O m3/hr.
Recycle gas; This is measured by an orifice plate which
is read t6 the nearest 5 cfm. The readings fluctuate
mildly when higher than about 45 cfm/ appreciably at
40 cfm and wildly at 25 cfm. In addition the recycle
gas is approximately saturated with water vapour. Since
the actual degree of saturation is not measured, the
water vapour content is calculated by assuming 95%
saturation at the exit temperature from the gas recycle
venturi scrubber. The error of temperature measurement
has been estimated at + 2°C; assuming a temperature of
7O°C and the water vapour equation:
H20 = exp (0.4329 Tr + O.3232) % by volume
which gives 31.19% v/v at 72 °C and
26.23 at 68*C or an error of + 2.48%
on a value of 28.6% v/v
Combining this value with + 5% likely error in the
assumption of 95% saturation we have:
( (7 dfl} ^ ^
% error of H2O content = 1OO j j JJTf +
= 10.1%
say + 10% .
Because of the wide variation in the fluctuation error/
the cumulative reading errors are estimated at 3 levels:
- 528 -
-------
All errors in cfm.
Level (cfm) 25 40
reading round-off 1.25 1.25
fluctuations 1O 5
orifice tolerance (1%) O.25 O.4
orifice calibration (1%) 0.25 0.4
Total 10.1 5.2
The cfm readings are corrected for pressure, temperature
and for the effect of water vapour content on the specific
gravity. The error of the pressure reading is + 2 on a
reading of 12 inches water gauge and that of temperature
reading is + 2*C, as mentioned above.
The calculations are (see ZKDAT in Appendix K) :
(34.247 x (12 + 407) _ )*
_
(7o + 273) (3o.4 - .124 x %H20) J
wet flue gas flow = 1.628825 (4.556 + .97121Z) ...... (2)
where term in brackets represents the orifice correction
and 1.628825 is the conversion factor from SCfm to m3/hr
and incorporates temperature correction from 6O°F to O°C
and pressure corrections from 1 at to 1 bar.
viz: scfm at 6O°F, 1 at to cfm at O°C, 1 at,
conversion = 492
520
cfm at OaC, 1 at to m3/h at O°C, 1 at,
conversion = 1.699O11
m3/h at O°C, 1 at to m3/h at 0°C, 1 bar,
conversion = 1.01325O
therefore 492 x 1.699011 x 1.01325O
520
= 1.628825
dry flue gas rate = wet flue gas rate (1 - .01 x H2O) .. (3)
Errors: Terms in brackets, eq. (1) :
Top line (12 has error of + 2) = 14349 + 68
Bottom line, value = 9210.8
- 529 -
-------
r, U 2 ) _,_ (.124 x .1 x 28.6 )*) '
Fractional error - | (70 + 273) + (30.4 - .124 x 28.6) f
= O.0144
therefore: bottom line = 9210.8 + 133
fractional error of the term multiplying cfm in eq. (1) is
iflw)2* (9JI§^)V=°-0076
on a value of 1.2481
the fractional error on Z = (.OO762 + {err°*f;!;n cfn>j V
\ cim ) )
Equation (2) does not introduce any error.
Equation (3) introduces an error through the water term,
the fractional value of which at 70°C is:
O.01 x 28.6 x 0.1 _ n A4
1 - 0.01 x 28.6~ U'U4
We can now calculate the total errors associated with
the recycle gas measurement and calculations at the
three levels considered above:
Recycle gas error calculation
level (cfm) 2_5 40 9O
total reading error (cfm) 1O.9 275 2.5
multiplying term (T,P,H20
correction) ^ 1.2481 >
multiplying term fract. ^ o ,
Z (eq.(l)) error 31.20 49.93 112.33
error of Z O.436 O.130 O.031
Wet gas flow m3/h
(eq.(2)) 56.77 66.41 185.12
Water vapour content < 28.6% v/v —>
Dry flue gas rate m /h
(eq.(3)) 40.5 61.7 132.2
Fractional error of dry
flue gas O.438 O.136 O.O5O6
Absolute error of dry
flue gas, m3/h 17.7 8^ 6.7
- 530 -
-------
Plenum Gas; The mixed fluidising air and recycle gas
are sampled from the plenum chamber and are analysed
for oxygen and carbon dibxide.
A comparison between the analysed and calculated oxygen
and carbon dioxide gives a check on our measurements,
indeed , the analysis of the likely errors of these
measurements led us initially to realise that the flue
gas recycle is approximately saturated with water. The
plenum gas is cooled and dried.
02: in the plenum is determined by a Servomex para-
magnetic analyser which gives a very steady reading.
Since the reading is roughly half-way between the
calibration points the likely error is probably higher
than 0.2% assumed for the lower readings ( regenerator
and flue gas) .
Assumed error + o.3% (absolute) .
C0_2: in the plenum is measured by an identical
instrument to that used for the regenerator CC>2;
the error can therefore be assumed the same, i.e.
O.O46 x % CO2 + 0.09 (absolute).
Flue Gas: it is sampled via a hot cyclone and filter
and then a two-stage water condenser. It is analysed
for:
9.2 • by a Servomex, error + 0.2% absolute
C02: scale reading 10 - 100, reading error 2.1
divisions (see regenerator S02 and CO2) .
Calibration gas tolerance + 5%
5% CO2 gave a reading of 42, reading error 6.6%.
total error = (6.62 + 52) h = 8.3%
absolute error at 5% = 0.41%
1O% CO2 gave a reading of 67. reading error = 3.7%.
total error = (3.72 + 52)^ = 6.2%
absolute error at 10% = O.62%
Absolute error of flue gas C02 = 0.042 x % CO?. + 0.2Q
SO?- measured by a Wostoff conductimetric analyser
calibrated in ppm with a reading error of + 5%
(estimated) and calibration gas error of +~5% giving
a total error of + 5.8%. The SO2 content~is corrected
for solubility in condensed water.
531 -
-------
4. Example of Gasifier Measurement Errors - Plenum Gas
Using data from Run 6, 6.19OO: Fluidising air = 432.8 + 6.9
m3/h
°2 = 90.9+1.4 m3/h
N2 = 341.9 + 5.5 m3/h
Dry flue gas = 1O6.5 +7.3 m3/h; water vapour = 42.7 + 4.5 m3/h,
Analysis: 02 = 1.95 + 0.2
CO2= 13.65 + 0.77
N2 = 84.4 + 0.8 (by difference)
Rates: ©2 = 2.1 + O.3 m3/h
C02 = 14.5 + 1.3 m3/h
N2 = 89.9 + 6.2 m3/h
Dry plenum gas = 539.3 + 10.O m3/h
Measured ©2 = 18.1 + O.3%, calculated O2 = 17.24 + 0.42%
Measured C02= 2.05 + 0.18%, calculated = 2.69 + 0.25%
The discrepancy between the calculated and measured
concentrations is marginally outside the likely error range
and it is probably caused by solution of CO2 in the wash water.
The discrepancy increases at lower recycle rates, at which
the error of recycle gas measurement also increases. For
these reasons, at plenum gas 02 concentrations in excess of
17.5%, the dry flue gas recycle rate was calculated from the
oxygen contents.
5. Balances
Apart from the streams already described/ data on flue gas
rate, oil analysis, solids analyses and product gas analyses
were needed.
Repeat oil analyses are given in Appendix J Table I. Since
the same oil supply was used in both Run 6 and 7 and a number
of samples were taken during each run, sufficient data was
obtained to calculate precision.
A number of repeat analyses were carried out on BCR 1359 lime-
stone. These are shown in Appendix J Table II.
The gasifier product gas samples were taken at 6.19OO during
Run 6. The analyses, correction for air contamination and
- 532 -
-------
errors (as estimated by our Analytical Dept.) are listed in
Appendix J Table III. The nitrogen, as analysed by gas
chromatography/ contains nitrogen only; the corrected nitrogen
also contains inerts.
The solids were analysed by wet chemistry with the precision
of +0.15 on total sulphur and + O.I on sulphate sulphur.
The~precision of carbon analysis has not been established and
has been assumed, arbitrarily, to be + 2O% of the value for C
content of less than 1% and + 10% for C contents of 1% or
more. The departures of the interpolated values from actual
are, of course, unknown; the interpolated sulphur content
have been assumed to have an error of O.25%. The inter-
polated removed solids are assumed to be + 2O% correct for a
spot reading; cumulative totals are, of course, much more
exact.
Gasifier product gas flow was calculated from nitrogen
balance:
Total Air = 468.5 + 7.0 n»3/h, at 79%, N2 = 37O.1 + 5.53
m3/h
Dry flue gas - 106.5 + 7.3 m3/h, at 84.4 + O.8% N2 =
89.9+6.2 m3/h
Total N2 in -. 460.0 +8.3 m3/h.
Let dry product gas flow = Q m3/h at 56.35 + l.O%
therefore: Q = 816 +21 m3/h - 35.93 + O.92 kmols/h
6. Gasifier Carbon Balance (kmols/h) Run 6, 6.190O
Input:
oil 195.35 + 0.39 kg/h at 85.3 + .36% -
13.88 + O.O6 kmols/h
Recycle CO2 = 14.5 + 1.3 m3/h = 0.64 + O.06 kmols/h
Limestone = 19.75 + 1 kg/h at 40.6 + 1.3 wt% CO2
~ = 0.6"6 + O.04 kmols/h
Total input = 15.18 + O.09 kmols/h
Output;
Product gas = 35.93 + 0.92 kmols/hr, composition as in
Table III.
- 533 -
-------
CO
CO2
CH4
C2H6
C2H4
C3H6
4.78
2
2
86
31
0.43
3.02
0.07
O.2O
0.16
O.095
O.O78
O.O65
+ 0.13
+ 0.010
+ 0.029
Total 13.67 + 0.25
Regenerator product gas flow (see p. 526)
Regenerator CO2 =» 4.2 +0.28 %
therefore: carbon out of the regenerator
Carbon out in solids
Interpolated
solids rate,
kg/hr.
Regenerator
cyclone
Elutriator
fines
Boiler back
Boiler flue
3.38 + 0.68
0.38 + 0.08
2.44 + 0.49
2.03 + 0.41
Interpolated
carbon wt%
O.53 + O.ll
21.4 + 2.1
O.34 + 0.07
5.88 + 0.59
31.96 + 0.48
m3/h
0.06 + 0.004
kmols/hr.
Carbon out
kmols/hr.
O.OO15 +
O.OOO4
0.0068 +
0.0016
0.0007 +
.0002
O.OO99 +
O.O022
Total 0.019 + O.OO3
therefore: Total output = 13.75 + O.25 kmol/h
Carbon recovery = 90.6 ± 1.7%
Since tar and possibly light hydrocarbons >C4 may have
been present in the gas but were not analysed, it is
probable that they account for the missing 9.4 + 1.7%
carbon.
- 534 -
-------
7. Gasifier Hydrogen Balance
Input:
oil 195.35 + O.39 kg/h at 11.28 + O.18
= 21.86 + 0.35 katoms/h
steam 42.7 + 45 m3/h = 3.76 + 0.40 katoms/h
Totat input = 25.62 ± 0.53 katoms/h
Output;
product gas 35.93 + O.92 kmols/h, composition as in
Table III.
H2 = 7.87+0.27 katoms/h
CH4 = 9.24 + 0.31
C2He = 1.29 + 0.20
C2H4 = 6.O4 + 0.27
C3H6 = O.13 + O.O2
C = 0.4O + O.O6
Output total = 24.97 + 0.53 katoms/hr
Hydrogen recovery = 97.5 + 2.9%
Water vapour was not measured in the product gas and
also the tar (possibly 1.43 + O.27 kmols/h of carbon
and therefore l.O - 1.5 katoms/h of hydrogen) are not
accounted for.
8. Gasifier oxygen Balance
Input;
Air O2 468.5 +7.0 m3/h = 8.66 + 0.13 katoms/h,
Recycle O2 1O6.5 +7.3 m3/h
at 1.95 + O.2% = 0.18 + 0. 02 katoms/h
recycle CO2 14.5 + 1.3 m3/h = 1.28 + 0.11
recycle H20 42.7 + 4.5 m3/h = 1.88 + O.20
Transfered as 804 from
regenerator (see p. 527) = 0.14 + O.O3
Total Input = 12.14 + O.27
- 535 -
-------
Output!
Product gas 35.93 + O.92 kmols/hr, composition as in
Table III.
CO = 4.78 + O.16
C02 = 5.72 + 0.19
Total output = 1O.50 + O.25
Oxygen recovery =» 86.5 + 2.8%
This departure from balance has so far eluded us and
it will be investigated during Phase III of this work.
9. Gasifier Stoichioinetry
Carbon from oil = 13.88 + O.06 kmols/h requiring
13.88 + O.O6 kmols O2/h
Hydrogen from oil = 21.86 £ 0.35 katoms/h requiring
5.465 + 0.088 kmols O2/h
Sulphur from oil = 0.1517 + 0.0009 katoms/h requiring
O.1517 + O.OOO9 kmols 02 h
Total oxygen required = 19.5O + 0.11 kmols 02/h
Actual oxygen supplied as oxygen gas = 8.84 + O.13 katoms/h
therefore: Stoichiometry of gasification = 22.67 + O.36%
1O. Overall Sulphur Balance
The dry flue gas rate for the calculation of sulphur balance
was calculated from the nitrogen balance in the following
way:
Overall oil reactions are
C + O2 -*• C02
H2 + ^02 + H2O
N2 associated with each mole of O2 = 3.762 mols.
195.35 kg oil contains 13.88 + 0.06 kmol C which reacts
with 13.88 + O.O6 kmols of O2. Associated with the O2 are
52.22 + O.2~2" kmol N2. Also, the oil contains 21.86 + 0.35
katoms H- which react with 5.465 + O.O88 kmol O2 associated
with which is 2O.56 + 0.33 kmol N2.
- 536 -
-------
3.5 4- O.25 m3 of pilot propane required O.46 ± 0.03 mols
of 62 making 0.46 + .03 kmols of CO2 and 0.31 + O.05 kmols
of H2O. Associated with the 02 required for combustion are
2.9O + 0.21 kmols of N2-
We can now sum the dry gases:
CX>2 from oil combustion 13.88 +_ O.O6 kmol/h
N2 from oil carbon combustion 52.22 +_ O.22 kmol/h
N2 " " H2
C02 " propane
N2 "
C02 from limestone
C02 from recycle gas
20.56 + 0.33 kmol/h
0.46+0.03 kmol/h
2.90+0.21 kmol/h
O.66 + O.O4 kmol/h
0.64 + O.O6 kmol/h
Total 91.32 + 0.46 kmol/h
Let X = mols excess air, then:
%0 21 X
*U2 91.32 + 0.46 + X
but %02 = 1.95 + 0.2% measured.
therefore X =9.35+0.96 kmol/h
therefore total mols of Dry flue gas = 10O.67 +1.06 kmols/hr,
Also required for the balance are the contributions from
collected solids:
Interpolated Interpolated
solids rate, total S, wt%
kg/hr
Regenerator
cyclone
Elutriator
fines
Boiler back
Boiler flue
3.38 + 0.68
0.38 + 0.08
2.44 + 0.49
2.03 + O.41
4.49 + 0.25
2.75 + 0.25
3.15 + 0.25
3.99 + 0.25
Sout
kmols/h
O.O047 + .OO1
0.0003 +_ .OOOO7
O.OO24 + .00052
O.OO25 + .O0053
Total O.OO99 + O.O013
- 537 -
-------
Sulphur input;
Oil: 195.35 + O.39 kg/h at 2.49 + O.O14 %S
= O.1517 + O.O009 kmol/h
Limestone: 19.75 + 1 kg/h at O.25 + O.O6 %S
= 0.0015 + O.OOO4
Recycle: 106.5 + 7 m3/h at 163 ppm S
= O.OOO5 + O.O001
Total Input = 0.1537 + O.O01O
Sulphur output;
In flue gas: 1O0.67 + 1.O6 kmols/h at 325 + 16 vol.ppm
= 0.0327 + O.O017 kmol/h
In regenerator gas: 31.96 + O.48 m3/h at 7.4 + O.46 wt.%
= O.1O41 + O.O067 kmol/h
In solids {see above) = O.OO99 + O.O013 kmol/h
Total output = O.1467 + O.O07O kmol/h
Sulphur recovery = 95.4 + 4.6%
This calculation also gives the sulphur content of flue
gas and total sulphur input. Therefore we can calculate
the overall sulphur removal efficiency:
o -a v - total sulphur in - total sulphur in flue qas
S.R.E. total sulphur in
x 1OO
therefore: S.R.E. - 78.7 ± 1.4%
11. Summary;
Approximate errors of the derived quantities as a percentage
of the value: • •
Sulphur removal efficiency = + 2%
Regenerator selectivity = + 7%
Sulphur balance (overall) = + 5%
Gasifier carbon balance = + 2% (balance not closed)
Gasifier hydrogen balance = + 3%
Gasifier oxygen balance = + 3% (balance not closed)
Gasifier stoichiometry = + 2%
- 538 -
-------
APPENDIX J - Table I
cn
Analysis of Fuel Oil Used in
Sample No.
C wt. %
H wt. %
S wt.%
N wt.%
V ppm
Na ppm
Fe ppm
Hi ppm
Sp gravity
Conradson
carbon
Asphaltenes
50494
86.23
10.92
2.50
.35
310
39
54
.9580
11.12
5.1
Run 6 -
5O495
85.95
10.95
2.45
.37
30O
38
52
.959O
11.16
5.6
50591
84.93
11.45
2.49
.44
310
59
2
38
.9571
10.54
5.43
51072
85.19
11.21
2.50
.35
30O
33
3
37
-
51073
85. 30
11.33
2.5
.31
305
46
2
37
-
Runs 6
and 7
50928 51O25
85.12
11.22
2.50
.38
320
23
2
44
10.81
5.67
85.25
11.64
2.50
.37
310
40
2
35
10.58
5.47
51135
84.88
11.42
2.50
.30
305
32
2
36
_
51136
84.97
11.34
2.47
.31
3OO
37
2
35
-
Total
Mean
85.31
11.28
2.490
0.353
306.7
38.6
2.67
40.9
.958O
10.84
5.45
99.472
standard
error
.156
.077
.006
.015
2.2
3.3
.33
2.5
.OOO55
0.29
0.22
95% confidence
limits
.36
.18
.014
.034
5.1
7.7
.77
5.7
.002 4
0.81
0.61
+0.4O
-------
APPENDIX J - Table II
Analyses of Limestone BCR 1359
standard 95% confidence
1
Ui
o
1
Sample No.
CaO wt.%
MgO wt.%
SiO2 wt.%
A12O3 wt.%
CO2 wt.%
Fe203 ppm
Na2O ppm
S ppm
V ppm
Ni ppm
50444 50428 5O475 50416
56.7 57.1 55.6, 57.0
57.4
O.58 0.58 0.57, O.58
0.55
0.8 O.8 0.8, O.8
1.1
0.2 O.2 O.2, O.2
0.2
38.6 ^ -
66O
655**
<50
11 -
Notes: * estimated from
50489 50515
55.8 57.4
0.54 0.55
0.8 1.1
O.2 0.2
41. 0
490
160
0.24
79
6
other data
50618
57.0
0.55
O.8
0,2
38.4
491
126
<5O
16
50661**
56.6
0.55
0.8
0.2
38.6
536
113
0.28
<50
56
* 50669
56.6
0.6
0.8
0.2
38.6
543
1O2
O.24
<50
57
Mean
56.72
0.565
0.86
0.2
4O.6
544
125
0.25
<50
29
error
0.19
0.0061
O.O45
O.0095*
0.48
31
12.6
0.013
11
limit:
0.44
O.O14
0.10
0.02
1.3
86
40
0.06
31
** outlier, left out of error calculations
*** this sample was analysed for free CaO (as opposed to total Ca): found to be ^ 1%.
-------
APPENDIX J - Table III
Sample No. : 5O5O5(1) : 5O5O5(2)-
' ' " ' ' ' " Corrected % Error Mean Error
°2 + Ar
N2
N2 + inerts - 56.87 1.42 - 55.84 1.4O56.35 1.0
CO 13.0 13.36 0.40 12.9 13.27 0.4O 13.31 O.29
C02 7.8 8.01 0.24 7.7 7.92 0.24 7.96 O.17
, H2 10.4 10.68 0.32 10.9 11.21 0.34 10.95 O.24
en CH4 6.21 6.38 O.19 6.3 6.48 0.19 6.43 O.14
Gasifier Product Gas
analyses. Run
Determined % Corrected %
1.3
57.0
-
13.0
7.8
10.4
6.21
0.45
3.95
0.05
0.13
-
-
56.87
13.36
8.01
10.68
6.38
0.46
4.06
O.O5
0.13
Error
-
-
1.42
O.40
0.24
0.32
0.19
O.O9
O.2O
-•
0.03
Determined %
1.0
54.9
-
12.9
7.7
10.9
6.3
0.71
4.22
O.O6
0.15
C2H4 3.95 4.O6 O.2O *.a 4.34 0.22 4.2O O.15
C3Hg
O.O6 - O.O6 (O.O1)
c 0.13 0.13 o.oj U.J.D 0.15 0.03 0.14 0.02
-------
APPENDIX K
COMPUTER PROGRAMMES FOR ANALYSIS OF THE
CONTINUOUS RUN DATA
GENERAL
Time sharing computing facilities, rented on the Honeywell
Mk.III Foreground system, were used for data analysis. All
the programmes were written in FORTRAN IV. Data was entered
on paper tape into listable files (to allow easy correction),
After checking, correcting and interpolating the data is
written into a set of consistent binary files which are used
as the data base for calculating the sulphur removal
efficiency, balances, etc. The chart in Table K-l indicates
how the various programmes and files are used.
GENERATION OF DATA BASE
The hourly run data, consisting of selected temperatures,
pressures, flows and continuous analyser readings are read
into files RXDATA, where X = run number. The actual data
points used are described in Table K-2.
Files RXDATA are checked manually and translated by
programme ZKABCON into binary files BRXDATA. During the
conversion any instrument correction factors, which are
pertinent to run X, are applied so that files BRXDATA are
consistent regardless of any run-to-rua instrumentation
changes.
The binary files BRXDATA are scanned by programme ZKSD which
identifies intervals of more than one hour and records these
as well as the day-time of start-up and final shut-down on
a listable file SDX. This file is used to ensure day-time
coincidence of interpolated data with that of hourly run
data.
Weights of solids removed are entered into files STX in the
following order:
A(l) = Day-time
A(2) = solids drained from the gasifier
A (3) = solids drained from the regenerator
A(4) = solids from the regenerator cyclone
- 542 -
-------
A(5) = elutriator fines
A (6) = solids removed from the back of the boiler
A(7) = combined solids from the stack K.O. pot and
cyclone
A(8) = elutriator coarse solids
Missing values at any one day time are filled in with -1 for
easy identification. This data is processed by programme
ZKSTINT in the following manner: weight units are converted
to kilograms, A(2), A(3) and A(8) are used directly but the
day-time is corrected for the delay between draining, weighing
and recording; A(3) -A(7) are interpolated linearly to the
equivalent hourly collection rates. Any solids removed
during shut-down are ignored and any solids removed during
missing data periods are allowed for (N.B. "missing data"
periods are periods of normal gasification during which one
or more essential readings were missed). File SDX is used
to ensure compatibility of day-time with run data files and
the converted data on solids removals is written on to a
binary data file STBINX. A listing of programme ZKSTINT is
provided in this Appendix.
Analytical data on the removed solids is written, in the
same order as the solids removal, into files YX, where Y =
analytical identification (Y=S for total sulphur, Y=O for
sulphate sulphur, Y=C for total carbon, Y=V for vanadium,
etc.) and X = run number. These files are interpolated
linearly to equivalent hourly values using programme ZKANINT
ensuring compatibility of day-time by reference to file SDX.
The interpolated analyses are written into files YBX where
Y and X have the same meaning as above. A listing of ZKANINT
is provided in this Appendix.
Chemical analysis of the oil and limestones as well as the
day-times at which limestones are changed are entered into
files ZKPROPX and checked manually. Programme ZKANFIL
combines the analytical data from ZKPROPX, SBX, OBX and CBX
and the solids removed data STBINX into a single analytical
data file BRXAN. The two sets of files: hourly run data
BRXDATA and the interpolated hourly analytical and solids
removal BRXAN as well as the derived data files JIMX
(described in the next section) constitute our data base.
- 543 -
-------
DATA ANALYSIS
The data base files are worked up by programme ZKDAT which
converts all the gas flow meter readings into cubic meters
per hour at 0"C, the oil and limestone readings into kilograms
per hour and analyser readings into percentage concentrations .
Flue gas recycle is corrected for 95% saturation with water
vapour. Measured SO? concentration in the flue gas is
corrected for solubility in water knocked out as the sample
is cooled. Sulphur removal efficiency is calculated as:
% Efficiency = 100 (total sulphur in -S in f luejas^f lue)
( total sulphur in )
where: total sulphur includes the sulphur from oil and lime-
stone and sulphur in the flue gas recycle at half the
concentration of SO2 in the flue gas. The figure of half the
concentration is based on some rough measurements before and
after the gas scrubber, measuring the S02 with a Drager tube.
Flue gas rate was calculated from nitrogen balance as follows:
Atoms C from oil and propane -C out of regen -C in fines = Co
Atoms H from oil and propane -H out of regen -H in fines = H0
Mols oxygen to combust the above = Co + fcHo
79
Mols nitrogen associated with oxygen = «y (Co + fc Ho)
Note: the contribution from N2 associated with 02
for sulphur combustion is negligible.
C02 from flue gas recycle and limestone = C02
with X mols excess air, the total boiler dry mo Is are:
BDM <= C0 + C02 + |Y (C0 + k H0) + X
Measured oxygen in the flue gas - Of
therefore Of = °X x 100 %
elimination of X and rearrangement gives
BDM = <21 " °fj Uff co + C02 + M Ho>
( 21 )
- 544 -
-------
It has been assumed that the carbon deposits have an average
composition CHQ.5 and therefore O.25 moles ofH2O are formed
in the regenerator for every mole of 003 measured. Gas
chromatographic measurement of water content in the regenerator
off gas have confirmed the presence of O.3 - O.4% H2O.
NOTE; This value of BDM can be used to calculate
the 02 and N2 required for combustion of
sulphur and recalculated. However, such a
correction was found to be negligible.
Selectivity of oxidation of CaS to S02 is calculated as
follows :
Mols CaS to CaO = mols S02 out of the regenerator
This represents the reaction
CaS + 1%O2 -»CaO + SO2
The balance of oxygen is assumed to react to form CaS04 by
the reaction
CaS +
Therefore:
Mols CaSO4 = ij (mols 02 in -1.5 x mols 02 out of regenerator
as 02, S02/ C02 and % H20)
% selectivitv = 1OO (Mols CaS to SOa _ )
* selectivity luu (Mols CaS to S02 + mols CaS to CaS04)
The total mols of regenerator off gas are calculated from
nitrogen balance.
Other calculations should be self explanatory from the
programme ZKDAT, a listing of which is attached. The values
calculated by ZKDAT are written into binary files JIMX, where
X = run number.
The actual output tables are produced by a series of programmes
ZKWRT1, ZKWRT2 etc. which read files JIMX and produce the
output tables in the correct format.
- 545 -
-------
CUMULATIVE SULPHUR BALANCE
All the data for an overall sulphur balance are contained in
files JIMX. The following data are abstracted.
Sulphur input = moles of sulphur in the fuel oil
+ moles of sulphur in the limestone
•t- moles of sulphur in recycle gas (taken at
half the concentration in the flue gas).
Note: the contributions from the limestone and recycle gas
are usually negligible.
Sulphur output = SC>2 in flue gas x boiler dry moles
+ S02 in regenerator off gas
+ total sulphur in solids removed (calculated
as interpolated total sulphur x interpolated
solids).
The error in the interpolated values may be considerable but,
since the contribution of sulphur in the solids to the total
balance amounts to only a few percent, the absolute error
of this contribution is also small.
The accumulated hourly sulphur inputs and outputs and the
accumulated difference are printed out in Appendix tables
BVl,CVl & DVl. In both runs 6 and 7 the cumulative balance
runs close to 100% throughout the run.
CUMULATIVE SOLIDS BALANCE
Data for these balances was taken from files JIMX.
Solids balance was calculated in terms of kilograms equivalent
burned stone (e.b.s.)
For limestone:
e.b.s. » wt of limestone x (l.O - O.O1 x % C02 in stone)
For removed solids:
e.b.s. * wt of solids x (1.-.O1 x C- .OO5O1 x S - ,01996
x S04)
where C = total carbon wt.%
S * total sulphur, wt.%
total sulphur present as sulphate, wt.%
- 546 -
-------
input e.b.s. = limestone e.b.s.
output e.b.s. = sum of interpolated e.b.s. removed from
gasifier, regenerator, regenerator cyclone,
elutriator fines, back of the boiler, flue
K.O. pot and cyclone and elutriator coarse
material when it was not returned to the
process.
The cumulative balances printed in Appendix tables, B.VI to
D.VI do not include any material removed during shut downs.
SNAPSHOTS
A programme ZKSNAP picks out any specified period of time
and calculates average values for that period, using data
in files JIMX.
Concentration averages are biased:
mean concentration = Concentration x rate
Other values are calculated as arithmetic averages.
In addition to the mean values, the programme calculates
root mean square deviations which serve as a measure of
stability of the data during that period. For values which
are averaged directly the root mean square deviation is:
Sn-
O • U • "~ /
/ N
where Xi = i th value of a variable measured
N = total number of values averaged.
For more complex values the r.m.s. deviations are combined
by the usual rules of combining standard deviations.
A listing of ZKSNAP is attached.
- 547 -
-------
ZKSTINT 05/22/74
100C THIS PROG. READS DATA FROM STX AND INTERPOLATES IT TO HOURLY
110C VALUES OF SOLIDS WITHDRAWALS- THE INPUT DATA IS EXPECTED IN THE
120C FORM: D.H* GASIFIER* REGENERATOR, REGEN. CYCLONE* ELUTR. FINES
130C BOILER BACK* BOILER FLUE *DHB(20)*SD(21)
200 REWIND 1
210 REWIND 21 ENDFILE 2
220 REWIND 3
230 DO 145 J=l*8i DO 144 K=1*500M44 BCJ*K)=0.)145 CONTINUE
240 K=l
250 RE ADO* 1 61 > DH0* DHF* NUM* ( DHEC J> * DHBC J) » J = 1 * NUM)
260 DHF=FNDH(DHF>
270 160 READC1* 161 *END=2l0>DJ 161 FORMATCV>
280 IFCDC1)-DH0+.0001>160*180*180
290 180 AC1*K>=FNDHCDC 1»
300 DO 201 J=2*8J 201 ACJ*K)=DCJ>
310 K = K+U IF(A< 1*K-1>-DHF> 160* 160*210
320 210 KMAX=K-1
330 SD(1)=FNDH(DH0)
340 DO 241 J=1*NUM
350 DHECJ> = FNDHCDHECJ»J DHBC J) =FNDHC DHBC J» 1 SD(J+ 1 ) =SDCJ)+DHBCJ>
360* -DHECJ)-!.
370 241 CONTINUE
380 250 DO 460 J=2»8
390 IC=HTK = 0.J S=0.J TB=0.J ACUM = 0.
400 DO 452 K=1,KMAX
410 RT=A(1*K)
420 300 IF(RT-DHEUC) )340*340*310
430 310 IF450*450*322> 322 IFCJ-7>323*323*450
460 323 ACUM=ACUM+A(J*K)| GO TO 450
470 330 IC=IC+1I IF(SD*.45359
540 IF370*370*360* 360 IFCJ-7)380*380*370
550 370 KN=INT(RT-1.5)
560 IFCKN)450*450*37l
570 371 IF (A(J,K))450*373*373
580 373 B(J*KN)=A
-------
- 2 -
ZKSTINT 05/22/74
600 390 S = S + A( J»K» TB=RTJ GO TO 450
610 400 EM = A< J*K>/JDEL= = S + DELlS=0.JA(J*K)=ACJ>K>- DEL
630 420 TK=TK+1.
640 IF(RT-
720 IF(RT-DHEUC> + .01>520* 510*510
730 510 IC=IC*1
740 520 X=INTCRT/24.»; XX=RT-24.*Xl XXX=INT*6.+ . 1)
760 B( 1*J)=X+XXX/100. + XX/1000.
770 DO 550 1=1*8* 550 D=B
780 WRITE<2)D
790
800 580 CONTINUE
810 STOP! END
820 FUNCTION FNDH
830 X=INT(V>J XX=INTC100.*(V-X)+.001>
840 FNDH=24.*X+XX+
-------
ZKANINT 05/24/74
00C INTERPOLATION
10
20
30
FILELIST "S6"*
DIMENSION AC8*
REWIND 1
• •
OF
ANALYTI
SB6
400
40 REWIND 2? ENDFI
50
60
70
80
90
200
2 IP1
220
230
240
250
260
270
280
290
300*
310
320
330
340
350
360
370
380
390
400
410
420
430
440
450
460
470
480
490
500
510
520
530
540
550
560
570
580
590
REWIND 3
READC 1* 1 61 )V1
DO 1 45 J= 1*8J
K=l
READC3* 161 )DH0
DHF=FNDHCDHF)
160 READC 1*161
IFCDC 1 )-DH0«-.0
180 AC 1*K)=FND
DO 201 J=2*8»
K=K+1S IF=FNDHCDH0
DO 241 J=1*NUM
LE
DO
*
*
0
H
)
1
DHF
tt
*
2
*
t*
BC
44
*
END =
01
CD
)
C
201
K
)
- 1
>
1
1
CAL SOLIDS DATA FROM SX*OX OR CX
SD6"
8
K
NUM
2
6
)
AC
1
0
)
J
*500>*DC8)*CC8)*DHEC20)*DHB<20>* SDC 21)
= 1*
5001 144 BCJ,K)=0.J 145 CCJ)=V1
*CDHEC J)* DHBC J)*J=1 * NUM)
0>D;
,
»
180
K> =
,
D
-DHF) 160
DHECJ)=FNDHCDHEC JMl
-DHECJ)-! .
241 CONTINUE
250 DO 460 J=2*
IC=1* KT=UTB=
0
8
e
DHBC
J
161 FORMATCV)
180
CJ)
* 160*210
) = FNDHCDHBC J) ) J SDC J* 1 ) = SDC J ) + DHBC J
DO 452 K=1*KMAX
RT=AC 1*K)
IFCACJ*K))450*
300 IF(RT-DHEC
310 IFCRT-DHBC
330 IC=IC*li I
331 TB=TB-CSDC
332 CONTINUE
340 CONTINUE
341 RT=RT-SD +
510 IC*IC*1
.
520 X=INTCRT/24
IC>
01
.)
)
J
5
2
0
,
XX*
510
,
510
RT-24.*XJ XXXsINTCXX)
- 550 -
-------
- 2 -
ZKANINT 05/24/74
600 XX=INT((XX-XXX)*6.+.1>
610 R< 1*J>=X + XXX/100.+XX/1000.
6?0 DO 550 1 = 1*8
630 IF(B(I* J>^ 551* 550* 55PI; 551 B(I*J^=0.J 550 C(I>=B(I*J)
640 WRITE(2>C
650
660 580 CONTINUE
670 STOPl END
680 FUNCTION FNDH(V)
690 X=INT(V>J XX=INT(100.*(V-X>+.001)
700 FNDH=24.*X+XX+(V-X-.01*XX>*1000./6.
710 RETURN* END
- 551 -
-------
ZKDAT 06/10/74
100C PROG FOR WORKUP OF FINES AND ANALYTICAL DATA FROM FILE BRXAN
110C AND RUN DATA FROM FILE BRXDATA* OUTPUT TO JIMX* X=RUN NO.
120 FILELIST "BR7AN"*"BR7DATA"*"JIM7"
130 DIMENSION D( 35) * Z A< 29 ) * CAOC 6) * C02C 6) t> SC 6) * DHFC 6) * A( 95)
140 REWIND U REWIND 21 REWIND 3IENDFILE 3
150 READC1)ZA
160 COIL=ZA( D/I201 o
170 HOIL=ZA<2>/201.6
180 SOIL=ZA<3)/3206o
190 SG60=ZA<4)
200 TOIL=200»
210 NLIMES=INT(ZA(5)+°01)
220 160 FORMAT(V)
230 DO 190 I=1*NLIMES
240 CAO(I)=ZA(4*I+2)J C02CI)=ZA(4*I+3)
250 S(I)=ZA<4*1+4)* DHF(I)=ZA(4*I*5)
260 190 CONTINUE
270 D0151 J=1*29J 151 A
280 DO 154 N=lp2* READ(1)ZA5 DO 153 J=1*29S 153 ACJ+29*N)=ZACJ)
290 154 CONTINUE
300 DO 155 J=88j>95* 155 A(J>=0o
310 WRITE(3)A
320 IHR=0
330 IDT=1
340 ILIME=1
350 240 READ(2*END=2200)D
360 READCDZA
370 IF *ZA( 1 ) J 147 FORMAT(1H o "I NCOMPATI BLE DoH "j.2F10o4)
390 157 EBST=0ol SS=0o| CT=0»
400 DO 158 J=U7l EBS=100o-ZA<22*J>-o50094*ZA<8 + J)-lo9963*ZA( 15+J)
410 EBST=EBST*o01*EBS*ZAC1*J>I SS=SS+»01*ZA<8+J)*ZAC1*J)
420 CT=CT<-o01*ZA(22*J>*ZA< 1*J)
430 158 CONTINUE
440 SRT=o0J*ZA(4)*ZA( 12)
450 DO 159 J=U29l 159 AC 66+J) =ZA( J)
460 241 A(52)=06
470 IF =lo
500 250 A<1)=D<1)
510 F=1...782E-4*CAO
-------
- 2 -
ZKDAT 06/10/74
600 424 CONTINUE
61 0C COMPUTE GAS COMPOSITIONS
620C BOILER COS
630 Z=(DC 11)/10.)- 1•
640 A<1])=.1418l778E-l+2.32l528*Z-.51096758*Zt2+.13242664*Zr3
650S.-. 13988354E- 1 *Z t 4+6.051 2861 E- 4*Z t 5
660C REGENERATOR COS
670 Z - CDC13)/10.)-1.
680 AC13>=1.1608245E-3+!.1574973*Z-.27330138*Zt2+.075628236*Zt3
690«-.00837005*Zt 4+•36410274E-3*Zt5
700C REGENERATOR S02
710 A< 14) =0. 10 39 5* (DC 14)-10.) t 1. 1 48*1. 426* C 1 .-EXPC-. 1 8* C DC 1 4) - 1 0 . > »
720 IFCAC14))428*428*429; 428 A(14)=0*0J 429 CONTINUE
730 A( 15)=DC 1 5)
740C PLENUM GAS C02
750 Z=CD(16)/10.)-1.
760 AC 16) = . 1 702439 5E-1 + 1 .1080589*Z-. 1 69 1 61 7 1 *Z t 2+. 36508 51 3E- 1*ZO
770A-2.844985E-3*Zt4+9.7723649E-5*Zt5
780 AC17)=DC17)
790C CONVERSION OF MEASURED FLOWS TO M3/H
800C GASIFIER AIR
810 AC 19) = 1.628825*C2.42+1.06091*DC 19))
820C FLUE GAS RECYCLE* P*T AND MOISTURE CORRECTION
830 H20FR=EXPC.04329*DC9)+.3232)
840 IFCAC17)-18.)615,615*612
850 612 DFGRsAC19)*C21.-AC 17))/CAC17)-AC10))
860 AC18)=DFGR/C1.-.01*H20FR)
870 GO TO 641
880 615 CONTINUE
R90 Z = DC18)*SQRT(34.247*CDC28)+407.)/(CDC9) + 273.)*C30.4-.124*HPOFR)))
900 AC 18) = 1.628825*C 4.556+.97121*Z)
910 DFGR=AC18)*C1.-.01*H20FR)
920 641 CONTINUE
930 H20R=.01*A(18)*H20FR
940C AIR TO INJECTOR AND BURNER
950 AC20)=1»628825*DC20)
960C AIR TO STONE FEED
970 AC21)=DC21)*SQRTCDC31>+14.7)*1.500 IE-2
980C AIR TO FINES RETURN
990 D( 34) = 12.9 69932+4. 1 33439*DC 34) +.066331 7 1 2* C DC 34) tf>.)
10004-1.3322994E-3*CDC 34)t3.)+l-5393257E-5*CDC 34)»4.)
1010 AC34) = 1.628825*DC34)*SORTCDC35)+407.)*1.7505E-3
I020C REGEN AIR
1030 AC25)sl.628825*DC25)*C407. + DC23
1040C N2 TO STONE
1050 AC22) = .4248*D(22)*SQRTCDC 31) +14.7)
1060C REGEN N2
1070 AC29) = 1.628825*DC29)*(407. + DC30
1080C PILOT PROPANE
1090 AC27)=.3427*DCS7)*SQRTCDC26)+14.7)
- 553 -
-------
ZKDAT 06/10/74
1100 AC 24) = 4.536924*DC 24)*C.9627+.06*SG60-.00036*TOIL)*SG60
H10C REGEN GAS FLOW BY N2 BALANCE
1 120 QREG=C79.*AC25) + 100.*AC29»/C 100.-AC I 4) - A( 1 3>* 1 «25- A( 1 5»
1130 A(32)=.453592*0(32)
1140C BOILER GAS FLOW
1150 QPROP=AC27)/22.1209
1160 BC=AC24)*COIL+3.*QPROP-AC13)*QREG/22I 2.09
1170 CSTG=AC32)*C02/C21 .-AC 10)>*BDM
1250 BO=.21*Z
1260 BN=BN+.79*Z
1270 BDM=BDM+Z
1280C CORRECTION OF BOILER S02 FOR SOLUTION IN CONDENSED WATER
1290 BS02-1.02362E-6*BDM*DC12>
1300 IF(BS02>1039,1039*990
1310 1039 A(12)=0.l BS02=0.J GO TO 1040
1320 990 BS02C=EXPCCALOGC7.6E-4*DC12)>-1»246>/l.282)
1330 BS02C=BS02C*CBH20-CHT+H20R/22.711-.02362*BOM)*2.8143E-A
1340 BS02=BS02+BS02C
1350 A<12)=BS02//2271.1
1470 CAOS=100.*CAOR/CCAOR+CAS04)
1480C STOICHIOMETRY
1490 02AC=CAC19)+AC20)+AC34)>*.0092466+DFGR*AC10)/2271.1
1500 02ST=AC24)*CCOIL+.5*HOIL+SOIL)
1510 ST=02AC/02ST*100.
1520C PLENUM CONC. OF 02 AND C02
1530 P02=CAC19)*21.+DFGR*AC10))/CAC19)+DFGR)
1540 PC02=DFGR*AC11)/CAC19)+DFGR)
1550C BED VELOCITY
1560 BV=8«5386E-4**A<34)*H20R)*CA<8)+273.)/CD(5)+407.
1570C REGEN VELOCITY
1580 RV=.01453*(A<25)+AC29))*CAC7)*273.)/+407.)
1590C CAO/S STONE FEED RATIO* MOLAR
- 554 -
-------
- 4 -
ZKDAT 06/10/74
1600 CASR=F*A<32>/AC24>
1610C CONVERSION TO ARRAY AND OUTPUT TO FILE
1620 A(23)=CASR
1630 A(26>=BV
1640 A(28)=P02
1650 A(30)=PC02
1660 A<31)=ST
1670 A(35)=SR
1680 A(36)=SREM
1690 A(37)=SIN
1700 A(38)=SREG
1710 AC39>=BS02
1720 AC40>=BDM
1730 A(41>=BO
1740 A(42)=BN
1750 AC43)=BC
1760 A(44)=CSTG
1770 A(45)=RV
1780 A(46)=02ST
1790 A(47>=02AC
1800 A(48)=CAOR
1810 A(49)=CAS04
1820 A<58)=CAOS
1830 A<50>=A<19>+A<20>+AC34>
1840 AC53)=BH20
1850 A(54)=QREG
1860 A<55)=H20R
1870 A<56>=DFGR
1880 A(57)=D(12)
1890 A<59) = CFGRJ A(60) = EBSTJ A(6D = SSJ A(62>=CTJ AC63)=CHT
1900 A<64)=SRTJ A<65)=A(32>*<1•-.01*C022160*2170,2120
1980 2110 IDT=IDT-76
1990 2120 ISHUT=0
2000 2130 IF(IDT-76>2150*2140*2140
2010 2140 ISHUT=ISHUT+24) IDT=IDT-100
2020 GO TO 2130
2030 2150 IDT=IDT+ISHUTl GO TO 2170
2040 2160 IDT=1
2050 2170 A(33)=XDT
2060 XDT^AC1)J A(66)=IDTI A(66)=A(66)+.00001
2070 WRITE(3)A
2080 GO TO 240
2090 2200 STOP I END
- 555 -
-------
ZKSNAP 05/24/74
100 FILELIST "JIM5"
1 10 DIMENSION AC95)*CAOC6)*DHFC6)*XC24)*PC8)*YC8)*SUMC 40)* SQC4PO
120 DIMENSION ZC42)*Z1C28)
1 3d DIMENSION DRC6)*DCC6)
140 REWIND 1
150 DRC1)=2.1530; DCC1)=3«0030; DR(2)=3.05301 DCC2)=3«1230
160 DRC3) = 11.2130; DC(3>=12.10301 DR<4)=12.14301 DCC4)=13.0330
170 DRC5)=16.1030; DCC5)=16.1830; DR<6)=17.1030; DCC6>=17.1930
180 READ( PA
190 NLIMES=INTCAC5)+.01)
200 DO 150 J=1*NLIMES; CAOCJ)=AC4*J + 2); 150 DHFCJ)=AC4*J+5)
210 DO 1155 JDH=1*6
220 DH1=DRCJDH>; DH2=DCCJDH)
230 ILIME =11160 IFCDHJ-DHFCILIME)*.00001)171*171*170
240 170 ILIME=ILIME+l; GO TO 160; 171 CONTINUE
250 DO 180 J=l*40; SUMCJ)=0.; 180 SQCJ)=0.J NUM=0
260 190 READC1*END=1900)A
270 I FC INTC 10000. + DH1*. D-INTC 10000.*AC 1) + .1»210*210*19P)
280 210 IFCINTC10000.*DH2+.D-INTC10000.*AC1)+.1))500*220*220
290 220 IFCAC36)-99.99)230f230*190
300 230 NUM=NUM+1
310 XCD-AC8); XC2)=AC7)J XC3>=AC9)
3P0C X1=GAS'R T*X2=REG T* X3=G.REC« T
330 X(4)=AC24)J XC5)=AC32); XC6>=AC19> +AC 20)+AC34>J XC7> = AC56)
340C X4=OIL RATE* X5=STONE* X6=TOT. AIR*X7=DRY F.G.
350 XC8)=AC55); XC9)=AC25>; XC10)=AC27);XC11)=AC6); XC12)=AC51)
360C X8=REC.ST.*X9=REG AIR*X10=PILOT C3*X11=BED DEPTH*X12=BED SG.
370 X(13)=AC2)/«098064; XC14>=AC37); XC15)=AC26); XCI6)=AC45)
38P(C X13 = REG.DP.*X14=SIN MOLS*Xl5 = BED VEL. *X 1 6=REG. VEL.
390 IFCXC1l)-53.34)360*370*370
400 360 XC17)=XC11)*C4177.4+.095238*XC11)*C69.215+.0317*XC I 1)))
410* *XC12)/I000.; GO TO 380
420 370 XC17)=XC12)*C242.035*4.9064*CXC1D-53.34))
430 380 CONTINUE
440 X(18)=AC39>
450C X17=BED WT. KG.* X18=SOUT MOLS
460 XC19)=AC75); XC20)=AC82); XC21)=AC89)
470C X19=GS* X20=GS04* X21=GC
480 XC22)*A<76); XC23) = AC 83); XC24)=AC90)
490C X22=RS* X23=RS04* X24=RC
500 YC1)=AC15); YC2) = AC13); YC3)=AC14)J PC1)=AC54)J PC 2)=PC1)JPC 3)=PC 1>
510C Y1=R02* Y2=RC02* Y3=RS02* P1*REG. GAS FLOW
520 YC4) = AC17); YC5)=AC16); PC 4)=AC 19) +AC 56);PC 5)=PC4)
530C Y4=PLENUM 02* Y5=PLENUM C02* P4=PLENUM GAS FLOW CDRY)
540 YC6)=AC10)J YC7)=ACJ1); YC8)*AC12); P(6)=AC40)J PC7)=PC6); PC8)ap=SUMC24+J)+X
-------
- 2 -
ZKSNAP 05/24/74
600 GO TO 190
610C BEGINNING OF AVERAGING
620 500 XNUM=NUM
630 D0520 J=1,40J SQ< J) = SQ( J) - SUM< J)* SUMC J) /XNUM
640 IFCSQCJ))521*521.523
650 521 SQCJ)=0.J GO TO 524
660 523 SQCJ)=SQRTCSQCJ)/CXNUM-1•))J 524 CONTINUE
670 520 SUMCJ)=SUMCJ)/XNUM
680 DO 550 J=25*32J X=XCJ-24)*SQRTCCSQCJ)/SUMCJ) ) **2 + C SQCJ+8) /SUM( J + 8 ))**{>)
740 550 SUMCJ)*XCJ-24>
750C CALC. OF SHE
760 XC 1) = SUMC18)/SUMC14)
770 XC8) = C1.-XCI))*SQRTC C SQC 18>/SUM( 18»**2+< SOC 14)/SUM( 14»**?>*I00*
780 X<7) = < 1 «-X< 1»* 100.
790 X(5>=SUM(5)*CAO(ILIME>/5607.» X(6)*SO(5>*CAO/5607.
800 X(5>=X(5>/SUM(14)
810 X(6)=X< 5)*SQRT< (SQC 14)/SUM( 14))**2+(X(6)/X( 5»**2>
B20C CALC. OF SELECTIVITY
830 X(1) = SO(25)*SQ(25)+1.5*SOC27)*SOC27)* 1.125*SOC26>*SQC?6)
840 XC2) = SUMC25) + SUMC26)*1.125+SUMC27)* 1.5
850 X<3) = .01*C< SQC33)/SUM(33)»**2+XC1)/CXC2)*XC2)))*SUMC33)*XC?)
860 XC1)=.5*SQRTC.21*SQC9)*SQC9)+XC3)>/22*711
870 XC2)=.5*C.21*SUMC9)-.01*SUMC33)*XC2))/22.711
R80C CALC. OF CA/S RATIO
B90 XC4) = SUMC33)*SUMC27)/2271 . 1
900 XC3)=X(4)*SQRT(CSQC33)/SUMC33))**2+CSQC27>/SUM(27))**2)/227!.l
910 SEL=100.*XC4)/(XC4)+XC2))
920 SELSQ=SEL*SQRTCCXC 3)/XC4))**2+781»781*760J 760 NUM=NUM-76* N=0
950 770 I FCNUM-100) 780* 771, 77U 771 NUM=NUM-100J NstN+241 GO TO 770
960 780 N!JM = NUM + N; 781 ZC3)=NUMj ZC4)=XNUM
97P) DO 790 J=1»13J Z( 2* J+3) = SUMC J> t 790 ZC 2*J+4) = SQC J)
980 Z(31>=X<5>! ZC32)=XC6>I ZC33>=SUMC15)I ZC34)=SQC15)
990 ZC35)=SUMC16)t ZC36)=SQC16)J ZC37)=XC7)J ZC38)=XC8)
1000 ZC39)=SEL» ZC40)=SELSQ> ZC41)=SUMC17)J ZC42)=SOC17)
1010 PRINT 1000»Z
1020 DO 840 J=1»8J Z1C2*J-1)=SUM(24+J)I 840 Z 1C 2* J ) = SQC 24«-J>
1030 DO 850 J=1»6J Z1C15+2*J)=SUMC18+J)I 850 Z1C16+2*J)sSO(18+J>
1040 PRINT 1200*Z1
1050 1000 FORMATC1H ,//////22X15HRUN 5 SNAPSHOT/
1060*14X4HFROM,F8-4»3H TO*F8.4.F6.0*10H HOURS RUN/19XF5.0*
1070*19H USEFUL DATA POINTS//3X8HVARIABLE 12X5HUNITS7X4HMEAN7X4HS.D.
1080*/17H GASIFIER TEMP. 6X 5HDEG.C4XF8 . 1 * F 10 . 1 / 1 6H REGENERATOR -••-
1090*8X3H-"-5XF8.1*F10.1/8H RECYCLE5X3H-"-8X3H-"-5XF8.1»FIB.1/9H OIL FEE)
- 557 -
-------
- 3 -
ZKSNAP 05/24/74
I00A14X5HKG/HR4XF8.1,FJ0.1/6H STONE5H FEED I3X3H-"-5XF8•1*F10.I/
110A10H TOTAL AIRl3X6HNM3/HR3XF8•1•Fl0.1/13H DRY FLUE GASI1X3H-1'-5X
120AF8-1*F10.1/16H STEAM WITH F.G.8X3H-"-5XF8.1 *Fl0.1/10H REGEN.AIF13X
130*3H-"-5XF8.1,F10.1/14H PILOT PROPANE10X3H-"-5XF8.1 • f10 . t/
140A10H BED DEPTH13X2HCM7XF8.1*F10-1/9H BED S.G.11X13HDIMENSIONLESS
150AF9.3*F10.3/16H REGEN BED DEPTH7X2HCM7XF8.1 *F10.1/15H CA/S MOL. RAT.
160«5X13HDIMENSIONLESS*F8.2*F10.2/15H GAS'R BED VEL.RX5HM/SEC5XFR.?,
J 7PI«F1 0.2/1 4H REGEN -"- •"• 1 0X3H-"-6XF8 .2* F10.2/7H S. R. E. 1 6X7HPERCENT
180*2XF8.1*F10.1/12H SELECTIVITYI2X3H-"-5XF8.1 *Fl0.I/11H BED WEIGHT13X
19042HKG6XF8-1»F10«1/)
200 1200 FORMATC1H »/20X22HANALYSES WT. OR VOL. I/23X2H0214X3HC02IJX
210A3HS02/3X5HGASESI2X4HMEAN3X4HS.D.4X4HMEAN3X4HS.D.4X4HMEAN3X4HS.D./
220A12H REGENERATOR4XF8.2*F7.2*F8.1*F6.1,F8-UF6.1/13H PLENUM (DRY)
2304F10.1*F7.1,F9.l*F6.1*6X1H-5X1H-/15H FLUE GAS
1270 1155 CONTINUE
1280 1900 STOPI END
- 558 -
-------
Table K-l
Listable
PYniTA —
s°*t~:
STX
Files
.
S^ ^
s.
*
Data Preparation
Programmes
| ZKABCONXJ >
03 """
I ZKANINT! =>
Binary Data Work-up
Files Programmes
BRXDATA
!*• ^
^^
^^\
•QOVIVM ^
STBINX \
NiN
YBX ^
ZKDAT [
\
ZKANFIL!
Calculated data Output
Binary files Programmes
1 ZKWRTGh* Run da
^^ • 'a»Balanc
-> JIMX ^^^ I 2KSNAPU» Snapsn
in
ZKPROPX
Note; X = 5, 6 or 7
Y = S, 0 or C
Q = 1, 2 or 3
-------
Table K-2
DESCRIPTION OF DATA POINTS ENTERED IN RXDATA
D(l) = Day-time in the form X.YYZZ where X = day from the
start of the run, YY = hour (24 hr clock), ZZ =
minutes, e.g. 8.37 in the morning on 5th day -
5.O837
D(2) = pressure drop across the regenerator bed inches w.g.
D(3) = " " " " gasifier distributor, inches
w.g.
D(4) " " " " " bed, inches w.g.
D(5) = gasifier gas space pressure, inches w.g.
D(6) = pressure drop across 10" of gasifier bed, inches w.g.
D(7) = regenerator temperature, °C
D(8) = gasifier temperature, °c
D(9) = flue gas recycle temperature, °C
D(10) = flue gas 02 content
-------
APPENDIX L
GASIFIER PRODUCT COMPOSITION
Samples of gasifier product were collected in metal
containers and analysed for composition several times during
Run 5. Since the coke, tar, and heavy hydrocarbon portion
of the product is not measured by this procedure, an attempt
has been made to estimate the quantity and composition by
material balance on the gasifier itself.
The dry gas compositions measured were listed in Table n of
the text, and a summary of the material balance results and
estimated heavy product compositions was listed in Table 12.
The calculations made involve several assumptions. Examples
of these calculations and assumptions are presented in this
appendix.
Data from the operating period 26.O33O are used in the
examples.
• Air flow to Gasifier, SCFM
To plenum and fuel injectors
with stone feed
to cyclone inlet
235.8 SCPM
02 Feed = 235.8 x .03316 Ib Mole/O2/Hr
SCFM Air
= 7.819 Ib Mole/Hr O2
• Flue Gas to Gasifier
Oxygen and CO2 are measured on dried samples of flue gas in
continuous analysers. The rate of flue gas flow to the
gasifier is measured by orifice meter on wet gas. A
correction is therefore needed for the composition change due
to water.
- 561 -
-------
( lOO/Y )
Dry Gas Rate = (Wet Gas Rate) (loo/Y + X/Z)
Where Y = Vol.% C02 in Dry Gas
X = Vol.% H2O in Wet Gas
Z = Vol.% C02 in Wet Gas
The ratio X/Z is assumed to be .818 based on the composition
of the fuel oil. This assumption implies that composition
of the flue gas does not change during passage through the
flue gas scrubber.
For the example period, Y = 14.1
Wet Gas Rate =86 SCFM
SCFM
Dry Gas Rate = 86 |.^2_J / ^22^ + .818J =77.1
Dry Gas Rate - 77.1 x = 12.17 Ib Mole/hr
Inputs with Flue Gas
Mole/Hr CC>2 = Mole/Hr Flue Gas x Mole Fraction C02
C02 = 12.17 x .141 = 1.717 Mole/hr
02 = 12.17 x ,O22 «* .268
N2 = 12.17 x .837 = 10.19
Mole/Hr H2O = Wet Gas Rate - Dry Gas Rate
H20 = (86 - 77.1) x = 1.404
Inputs from Solids
Oxygen from regenerator sulphate
= (Lime Circulation, Ib/Hr) (Fraction S as 804) * 2
02 from Sulphate = 833 x * = .713 Mole/Hr
Oxygen from fresh stone Carbonate ^ ^
- (stone rate, Ib/Hr) (Wt. Fraction O>2 in Stone)/44
= 32 x .434/44 = 0.316 Mole 02/Hr.
- 562 -
-------
Oxygen from CaO + H2S -*• CaS +.._H_2Q
= (Mole/Hr S to gasifier) (S removal efficiency)/2
= (409.1 x .0248/32) (.9O6)/2 = .144 Mole O2/Hr
Total 02 Inputs to Gasifier
Air 7.819
Flue Gas 02 .268
C02 1.717
H20 .702
Sulphate .713
Stone C02 .316
CaO .144
11.679 Ib Mole O2/Hr
Nitrogen Inputs
Bed Air + Cyclone inlet flow + Stone feed Air
= 02 Rate x .79/21
= 7.819 x .79/.21 = 29.414 Mol/Hr N2
Bed Feed N, Bleed = .351 Mole/Hr
Injector N2 = .16 Mole/Hr
Flue Gas = 10.19 Mole/Hr
Pressure Tapping Bleeds = .03
Total N2 Inputs 40.145 Mole/Hr
Product Gas Rate = N2 Rate/fraction N2
= 40.145/.634 = 63.321 Mole/Hr
Oxygen Outputs in Product Gas C oxides
= (Fraction C02 + FrCO/2) (Product Gas Rate)
= (.1088 + .0936/2) (63.321) = 9.85 Mole O2/Hr
- 563 -
-------
0? Out as Sulphate
= (lime Circulation) Fr S as 804 = /32) x 2
= 825 x .0029/16 = .149 Mole O2/Hr
02 Out as H?0
The oxygen leaving the gasifier as water is assumed to be
the difference between the 02 inputs and other known 02
outputs.
02 in Water = 11.679 - 9.85 - .149 = 1.68 Mole/Hr
H2 Inputs to Gasifier
Hydrogen in with fuel = Fuel Rate x wt. fraction H2/2
= 409.1 x 0.114/2 = 23.319 Mole H2/Hr
Hydrogen in with flue gas = 1.404
Total H2 In = 24.723 Mole/Hr
Hydrogen Output in Product H2 + Hydrocarbons
£ (Mole/Hr Product) (Mole fraction x H2 Multiple)
As H2 = 63.321 x .0642 = 4.O65
As CH4 = 63.321 x .0609 x 2 = 7.712
As C2H4 = 63.321 x .O381 x 2 = 9.825
Total 16.602
Hydrogen Out as H?0
Moles H2 in Water = 2 x Moles 02 in water
H2 out in Water = 2 x 1.68 = 3.356
Hydrogen Missing
= Known Inputs - Known Outputs
= 24.723 - 16.602 - 3.356 = 4.765 Mole H2/Hr
Missing hydrogen is assumed to be in tars, coke and liquid
portions of products not measured by gas chromatograph.
- 564 -
-------
Carbon Inputs
With Fuel = Fuel Rate x fraction C/12
= 409.1 x .856/12 = 291182 Mole C/Hr
With flue gas = CO2 input = 1.717 Mole C/Hr
With limestone = Stone Rate x Mole fraction CC>2
= 32 x .434/44 = .316 Mole C/Hr
Total Carbon in = 31.215 Mole/Hr
Carbon Outputs
Carbon Out in Product Gas
= £ Product gas x Mole, fraction x C multiple
As C02 = 63.321 x .1O88 = 6.889
As CO = 63.321 x .0936 = 5.927
As CH4 = 63.321 x .0609 = 3.856
As C2H4 = 63.321 x .0381 x 2 = 4.825
Dry gas total C = 21.497 Mole/Hr
Carbon Out Regenerator
= (Mole/Hr Regenerator Gas) x (Mole fraction CO2)
= N2 to Regenerator = 2.902 Mole/Hr
N2 in Regenerator Gas = .951 Mole fraction
02 in Regenerator Gas = .017 Mole fraction
CO2 out = 2.9O2 x .017 = .052 Mol./Hr
.951
Carbon Missing
= Known Inputs - Known Outputs
= 31.215 - 21.497 - .052 = 9.666 Mole C/Hr
Like Hydrogen, the missing carbon is assumed to be in the
form of coke, tar, and other heavy components of the product
gas not measured by the gas chromatograph.
- 565
-------
CO/C02 Made in Gasifier
The CO2 made in the gasifier is taken as C02 out less CC>2
from lime stone and flue gas recycle
C02 made = 6.889 - .316 - 1.717 = 4.856
CO made = 5.927
CO/C02 = 5.927/4.856 = 1.221
H/C Ratio of Heavy Products
The H/C ratio of missing products is taken as 2 x H2 missing/c
missing
H/C = 2 x 4.765/9.666 = .99
Results of these component material balance calculations for
four gas samples are summarised here in Table L-l and in
Table 12 of the text.
Table L-l
Summary of Gasifier Component Material
Balances
Time
02 In, Mole/Hr
02 Out,
02 to H20 (Diff)
H2 to H20
H2 inputs
H2 in products
H2 missing
C inputs
C in Products
C missing
H/C in missing
CO/C02 Made
H missing, % of feed
H oxidised % of feed
C missing, % of feed
C oxidised, % of feed
22.103O 22.173O 26.O33O 26.173O
11.797
10.084
1.713
3.426
24.901
20.472
1.003
31.441
24.439
7.OO2
11.715
9.753
1.962
3.924
24.852
19.792
1.136
31.356
22.544
8.812
11.679
9.999
1.678
3.356
24.723
16.602
4.765
31.215
21.549
9.666
11.240
8.931
2.309
4.618
24.677
12 . 301
7.758
31.255
2O. 367
10.888
.286
1.102
4.3
14.6
23.9
35.8
.258
.97
4.8
16.8
3O.O
34.0
.986
1.22
20.4
14.4
33.1
37.0
1.43
1.36
33.3
19.9
37.4
31.9
- 566 -
-------
APPENDIX M
BATCH UNIT PROCEDURES
GENERAL
Several test procedures were employed to measure sulphur
absorption and dust producing characteristics of the stones.
These included fresh bed tests in which a new batch of
calcined lime was used for each test, cyclic gasification
tests in which a single batch of lime was cycled between
gasification and regeneration conditions, and kerosene and
fuel oil combustion tests in which the appropriate fuel was
burned in the fluid bed with excess air to control temp-
erature.
START UP AND CALCINATION
The bed is calcined by combustion of propane below the
distributor and by direct injection of kerosene into the
bed. First of all, the bed space temperature is raised to
950 deg. C. by gas combustion below the distributor. Then,
4OOOg of limestone is added. This is heated to 750 deg. C.
using gas before switching to direct kerosene injection.
Due to the strongly endothermic nature of the calcination
reaction, the temperature remains in the region of 8OO deg.
C. until CO2 evolution ceases. When the temperature rises
to 950 deg. C, indicating that calcination of the original
charge is complete, 25OOg limestone is added and calcined.
Further batches of this size are added and the procedure
repeated until the target bed depth is reached.
COMBUSTION TEST
For a test with kerosene combustion, the injection of
kerosene is continued with the bed past the point of
complete calcination. For fuel oil combustion, the fuel
supply is simply switched to heavy fuel oil from its heated
supply drum. The fuel rate is set to give a bed temperature
slightly in excess of the target, and fine adjustment is
carried out with the aid of a cooling coil. Relevant data
on gas analysis and unit behaviour are recorded and
appropriate bed and cyclone samples taken. Combustion is
continued for the required length of time.
- 567 -
-------
GASIFICATION TEST
To achieve gasification, the fuel supply is changed from
kerosene to fuel oil when calcination is complete, and oil
rate is increased to obtain an air/fuel ratio of about 25%
of stoichiometric. The sample flame burner and external
flare are lit and the gas analysers connected. Relevant
data are recorded and bed samples and cyclone samples taken
at prescribed intervals. Gasification is continued for the
requisite length of time.
REGENERATION
Regeneration of the sulphided stone from a gasification cycle
is performed by stopping the fuel supply and continuing the
flow of air. Oxidation of carbon and CaS in the bed raises
temperature to the regeneration level. Relevant temperature
and analytical data are collected, and a bed sample is taken
when regeneration is complete.
SHUT DOWN
At the end of a run, the bed temperature is allowed to drop
to 70O deg. C. before the bed is removed through the drain
point just above the distributor. Draining the unit is
much easier when the bed is hot since the solids flow
better under these conditions. When all the bed has been
removed, all ancillary equipment is shut off.
CYCLE TESTS
Cyclic tests are the nearest simulation to continuous
gasifier operation that can be obtained in batch units.
The same charge of lime is subjected to repeated cycles of
sulphur absorption and and regeneration. After each
regeneration a portion of lime is removed and replaced by
an equivalent amount of fresh limestone. The limestone
calcines to lime during the early part of the next
gasification cycle. Without replacement, the activity of
the lime bed gradually declines. With replacement, the
activity falls initially, but in a few cycles lines out at
an equilibrium level which is influenced by the rate of
replacement.
Enough cycles are performed at each set of operating
conditions to establish the lined-out sulphur removal
efficiency for those conditions.
- 568 -
-------
Cyclic tests use the same calcination and start-up
procedures as the fresh bed tests. However, after the
initial start, a series of gasification and regeneration
cycles follow each other. Sampling and gas analysis
procedures also are the same as used in fresh bed tests.
When a regeneration cycle is complete, the fluidisation
cools the bed very rapidly. Therefore the following
procedure was adopted.
(1) When regeneration was complete as indicated by end of
SO2 emission and fall of bed temperature, fluidising
air was stopped.
(2) Replacement limestone was added.
(3) Fluidising air was resumed and when temperature reached
the desired point, oil feed was resumed.
For the purpose of stone comparison, the target conditions
in each test were the same.
- 569 -
-------
APPENDIX N
Batch Data
Table
1 Cycle Test conditions and SRE's (Test 1-E)
2 " " " {Test 2-E)
3 " " " " " (Test 3-C)
4 " (Test 3-D)
5 " " " " " (Test 3-E)
6 " " " " " (Test 4-C)
7 " " " " " (Test 5-D)
8 Cyclic Test Conditions for High Sulphur Pitch (Test 6-C)
9 Kerosene Combustion (Tests 1-A, 2-A, 3-A, 4-A)
10 " " (Tests 1-B, 2-B)
11 Fuel Oil Combustion (Tests 1-C, 2-C)
12 Fuel Oil Gasification (Tests 1-D, 2-D, 3-B)
13 Kerosene Combustion on Cycled Bed (Tests 1-F, 2-F)
14 Gasification of Heavy Residual Fuel Oils, Fresh
Bed Test Results (Tests 5-A, 5-B, 5-D)
15 Gasification of Heavy Residual Fuel Oils, Fresh
Bed Test Results (Tests 5-C, 6-A, 6-B)
- 570 -
-------
TABU H-l. CVCLE TEST COHOITIOHS AMP SHE'S (TEST 1-g)
tn
-j
Run
no.
7/72
8/72
9/72
10/72
11/72
12/72
H/72
14/72
15/72
It/72
17/92
It/72
19/72
2O/72
21/72
22/72
23/72
24/72
25/72
2(/72
27/72
28/72
29/72
30/72
LiMStone
Particle
Cycle Line- Slme Range,
Ho. Fuel •tone u
1 Aniay(2.3«S) BCR 1(91 (OO-317S
2 •
4 "
5 '
6 '
7 '
9 "
10 • '
11 " "
12 '
1J '
14 "
IS '
iS . • '
17
18 "
la • • "
19
2O
*» « " *
21
22 "
-i* •• " "
23
24
Total
Fuel Rate. Air,
g/«in 1/Bln
199
190
210
2OO
204
2O1
21(
216
206
212
23)
224
233
227
224*
213
216
227
233
226
238
244
247
(56
7O4
676
(33
(29
(38
(34
(40
(61
CC8
664
((9
(59
(47
641
(30
656
(38
634
622
63)
69O
679
(77
Superficial
Ga»
Velocity ,
•/sec
1.71
1.89
1.8O
1.C8
1.68
1.71
1.C8
1.71
1.74
1.77
1.74
1.77
1.74
1.71
1.68
1.74
1.68
1.62
1.83
1.8O
1.80
» Stoich
Air
11.2
34.0
29.5
29.0
28.3
29.1
26.9
24.9
29.4
32.9
28.7
26.3
27.0
25.5
25.9
25.8
28.3
27.1
25. 6
24.5
25.7
26.6
25.5
25.1
Bed Depth
Start End .
(4.8
45.5
49.5
52.1
49 -O
-
48.3
55.9
45.7
50.8
47.2
50.3
54.8
59.9
53.3 .
(2.S
47.2
48.8
54.4
54. (
55. (
53.3
54.9
56.4
52.6
43.4
47.5
43.4
41. <
44.2
-
48.0
42.7
46.5
45.7
45.7
48.8
50.3
5O.3
47.0
41.7
47.2
44.6
46.5
41.0
49.)
50.8
47. 0
Bed
Specific
Eravlty
0.(7
0.75
0.75
0.73
O.77
O.79
0.80
O.76
0.83
0.77
0.83
0.83
0.81
0.83
0.85
0.82
0.81
o.«w
0.83
O.84
0.84
0.83
0.81
Average
Bed Temp.
(Abiorptlon) ,
•c
630
850
845
845
855
85O -
850
845
830
850
835
840
840
840
835
840
840
840
840
830
84O
845
845
840
Max Bed
(•eoen) ,
•c
920
980
10OO
990
100O
1OOO
10OO
1O1O
955
10OO
loos
101 S
1O15
1010
1010
1010
990
1010
1010
1010
1010
1010
1020
1015
Duration Nake-up
of Height Cyclone
Abeorption, (Limestone), Duet.
•in g/cycle 9
40-500
7OO 81O
530
300
• • 285
• 2O5
no
• 24O
• • JOS
190
225
• • 2OO
245
242
250
2*0
30O
170
1(0
182
2O7
29O
2(0
• • 295
SRE,
k
1OO
loo
100
91
86
71
72
79
78
81
57
S7
72
72
72
74
77
73)
74
73
72
72
7(
71
-------
CTCU TEST COHOITIOHS AND SULPHUR IttMOVM. EFFICIENCY ITEST 2-EI
•vl
10
Run
Ho.
11/72
39/72
tO/12
41/72
42/72
43/72
44/72
4S/72
46/72
47/72
41/72
41/72
SO/72
SI/72
52/72
S3/72
S4/72
55/71
S«/72
57/72
58/72
LiBaatone
Particle
Cycle Li»e- Sii< Rta?t,
•o. ruel .ton* u
1 Mraay 12. )%«) Jj^7l>~ (OO-317S
2
3 - •
4 •
s •
« " •
7 • •
8 • •
9 "
10 •
71 -
12 •
13 "
14 - '
15 •
u •
17 '
18 '
11 '
2O ." " "
.
Fuel Hate
g/mln
114
203
214
221
241
241
241
218
243
2S3
254
247
2S»
244
213
238
23*
241
227
231
2)1
Total
. Air,
1/mln
700
443
671
613
60»
<45
414
t«4
433
645
C29
437
433
CU
(41
(41
(1(
(17
(05
(Ol
(01
Superficial
Gal
Velocity,
•/sec
1.84
1.71
1.83
1.74
1.62
1.74
1.68
1.10
1.71
1.74
l.(B
1.77
1.71
1.77
1.80
1.71
l.«
1.65
l.C
1.42
l.M
« Stolch.
Air
34.9
21.1
2«.>
2(.3
23.2
24.4
22.7
25.4
23.9
23.4
22.7
23.7
22.5
24.7
2t.5
24.1
23.8
23.5
24.5
21.2
23.7
Bed Depth
CMtlMtrec
Start End
48.0
47.2
41.3
45.7
31.9
41.4
41.9
41.4
44. 5
42.9
42.2
41.7
41.2
42.1
55.4
5(.l
5».2
(0.2
41.7
4».3
-
39.1
4O.9
37.1
4O.4
40.9
40.4
3(.8
37.3
35.8
37.3
38.3
40.1
4O.4
42.2
41.0
55.4
52.8
45.7
42.7
52.8
-
Bed
Specific
Gravity
0.83
0.84
O.84
0.8S
O.»O
0.94
0.97
0.88
0.92
0.94
0.95
O.»l
0.»2
O.»2
O. 74
0.72
0.73
0.7J
O.»2
0.83
-
Average
Bed Temf.
(Absorption)
•C
880
850
seo
890
850
860
870
• 7O
870
87O
850
870
850
8(O
875
845
850
8S5
870
8(5
845
Max Bed Duration
Te»f> of
, (Itegen) , Absorption
•C Bin
980 40
1010
101O
1010
1O1S "
1010
1020
97O
1010
1O20
1030
1030
1035
1025
»3O
180
10L5
1020
1020
1030
1030 '
Make-up
Meiqht Cyclone
, ILimeaton«J , Duat,
9/cycle 9
577
550 394
2»«
231
177
IIS
1(O
180
183
ISO
151
HO
120
158
140
1(0
1(2
1(0
17O
155
ISO
SRE .
%
100
100
90
87
77
85
74
75
74
7O
74
77
74
78
74
79
7(
77
77
75
74
-------
Tafcle «-3. CYCLE TEST CONDITIONS AMD SULPHUR R23CVAI. STTlClS»Ct (T«ST 3-CI
1
1/1
^ej
U)
1
Una
Ho.
62/72
63/72
64/72
65/72
66/72
67/72
68/72
69/72
70/72
71/72
72/72
73/72
74/72
75/72
76/72
77/72
76/72
79/72
6O/72
11/72
Cycle
•o.
1
2
3
,
5
6
7
1
9
10
11
12
13
14
15
17
ia
19
20
Limestone
Particle
Lime- Size Kai>9a, Fuel Kate
Fuel stone \t g/min
ABU*y(2.3%S) BCK 1359 6OO-3175 199
193
213
227
23O
233
" " 236
227
• 222
210
219
184
179
112
194
201
196
« • " 193
• • * 193
179
Total
, Air,
I/Kin
688
697
700
491
614
682
664
644
652
659
66O
650
637
639
650
631
«35
609
645
663
Superficial
Cat
Velocity,
•/•ec
1.69
1.8»
1.92
1.B9
1.83
1.86
1.80
1.80
1.80
1.80
1.77
1.74
1.74
1.74
1.71
1.7.1
1.74
1.65
1.74
1.80
t Stolen.
Air
31.7
33.1
30.2
27.9
26.9
26.9
25.1
26.8
26.9
28.1
27.6
32.4
32.7
32.2
30.4
28.8
29.7
29.0
30.7
34.0
Bad Depth
cent iawt res
Start End
48. 0
43.4
41.7
40.6
39.7
39.9
41.4
39.1
37.6
36.3
44.5
4S.7
47.0
46.5
43.7
47.2
41.9
47.0
51.3
36.9
37.3
37.6
36.3
37.1
34.3
35.6
36.1
36.1
35.6
41.7
42.7
43.4
42-7
40. •
41.9
42.7
43.2
41.1
-
Bed
Specific
Gravity
0.85
0.90
0.92
0.95
0.95
0.91
0.96
1.00
1.04
1.08
0.92
0.92
0.92
0.96
1.00
0.99
1.00
l.OO
1.04
-
Average
Bed Temp.
(Absorption)
•c
no
•40
880
•80
145
180
175
175
180
180
145
860
170
170
140
870
• 75
170
965
870
Max Bed Duration Hike-up
Twep of Height
. ( Regen) . Absorption , Limestone ,
•C eiin 9/cycle
' 935 40
9,0 " 550
1020
103O " "
1030
1030
1035
1025
1025
* •
990 ' "
995
1010
1010
1O20
1020
1015
1O20.
1020
990
Cyclone
Dust,
279
49S
361
34S
215
137
134
122
130
125
76
133
1O3
84
135
14O
1OS
92
•5
125
SU
94
15
12
12
75
76
71
ao
80
77
69
76
78
77
76
73
72
71
75
75
-------
Tabl« H-4 CYCLIC TEST CONDITIONS AMD S.K.I.'S ITBST 3-P)
Run Cycle
•o. Ho. ruel
41/73
42/7]
43/73
44/73
45/73
46/73
47/73
41/73
«i/73
SO/7J
51/71
12/73
SS/73
54/73
SS/71
56/71
57/73
51/73
SV73
60/73
1 Anuay(2.3%S>
2
3
4 "
S
6
7
8
,
10
11
12
13
14
IS
16
17
18
19
20
Liawatone Superficial
Particle Total Ga«
Liaw- Six* Range, Fuel Rate. Air. velocity, 1 stoich.
atone u g/oin l/«in n/MC »ir
BC« 1359 6OO-3175 172
no
" 172
176
179
1»9
211
J10
2O7
2O4
204
216
• • 213
225
247
254
252
243
244
281
665
69O
695
683
685
673
674
*76
70S
692
700
690
70O
700
785
690
680
4»0
«B8
68S
1.81
1.81
1.84
1.81
1.81
1.78
1.78
1.7J
1.88
1.84
1.84
1.84
1.88
1.88
2.09
1.78
1.76
1.84
1.63
1.82
34.
35.
34.
33.
33.
28.
28.
28.
29.
29.
29.
27.
28.
27.
27.
23.
22.
24.
24.
21.
6
3
7
6
4
7
1
1
6
6
7
»
5
O
5
2
3
7
4
0
Bed Depth
centinetrea
Start End'
48
51
55
54
54
43
49
52
49
50
47
46
50
44
40
45
46
48
44
44
50
52
50
50
49
42
45
46
47
45
46
46
47
44
39
41
45
45
42
~
Bed
Specific
Gravity
O-77
0.75
0.7«
0.82
0.83
0.7J
0.83
0.82
0.75
0.78
0.82
0.83
0.7J
0.83
0.82
0.78
0.61
0.83
0.84
0.80
Average Max Bed Duration
Bed Tea*. Tea*. of
(Atoaorption) , I Regan) , Absorption
•C -c Bin
860
855
955
860
860
8*5
860
860
850
855
865
865
87O
875
96O
855
8*0
86O
655
86O
960 40
1O2O "
- 1070
1O60
1040
1O4O
1O90
1O3O -
9*5
1010
1020
1030
1O3O
103O
1O25 •
1O30
1O4O
1035
1O3S •
1030
Weight Cyclone
, (Llaeatone) , Duit,
a/cycle g
139
750 115
128
143
148
151
16*
172
157
185
• 234
418
497
572
130
146
180
203
232
225
SHE,
92
92
89
83
89
•4
•0
80
82
84
84
82
85
83
75
76
70
<6
79
_a
* FUEL PUMP FAILED AFTEK 2S MIHS.
-------
Table X-5. CYCLIC TEST CONDITIONS MID S.R.E.'S ITEST 3-El
Ul
-J
en
Run
No.
61/71
62/71
63/73
64/71
65/73
66 /7 1
67/73
68/73
69/73
71/73
72/73
73/71
74/71
75/71
76/71
77/7J
78/71
79/71
80/71
81/71
cycle
HO. Fuel
1 AnuayU.ltS)
2
3
4
5
6 "
7
8
9 "
10
11
12
13
14
15
16
17
18
19
20
21
Limestone
Particle Total
Line- Size Range . Fuel Rate, Air,
stone u g/irun 1/min
BCR 1359 6OO-1175
196
164
170
no
244
184
173
225
230
199
2O1
183
204
" • 19O
193
• " 196
201
204
193
_
687
679
665
655
696
662
700
7 2O
670
66O
730
675
661
655
645
682
66O
641
675
693
Superf icia 1
Gas
Velocity, 4 Stoich.
in/ sec Air
-
1.78
1.81
1.81
1.74
1.52
1.76
1.87
1.95
1.78
1.73
1.95
1.80
1.76
1.75
1.72
1.61
1.74
1.70
1.79
1.96
-
32.6
18.3
36.3
35.4
22.7
33.2
37.2
29.7
27.0
3O.7
13.6
32.4
29.9
32.0
31.0
32.}
30.4
JO 2
30.7
34.3
Bed Depth
centimetres
Start End
-
48
50
50
52
51
55
53
44
48
47
41
49
46
47
54
44
46
46
45
47
-
46
Jb
44
52
52
S5
54
43
46
43
41
46
46
+7
47.
44
16
47
44
47
Bed
Specific
Gravity
-
.76
.75
.76
.78
.83
.78
.83
.77
.79
.77
.87
.61
.6)
.8)
.81
.81
.81
.92
.90
.89
Average
Bed Te*p.
(Absorption)
•c
-
830
865
87O
865
86O
860
87O
880
860
655
870
865
660
870
6(5
8(0
8 SO
853
8*O
870
Max Bed Duration
Te«p of
' (Regen) , Absorption
-
960 40
190
1O10
iO2O •
1030
1015
1010
104O
1040
1010
1015
102O "
102O
1025 «
1020
1000
1015
1015 •
102O "
102O
Hake- up
Weijht Cyclone
, (LiaMtone) . Duct ,
9/cycle
-------
Table H-6 Cycle Teat Condition. and SBIs (Test 4-C)
in
Htm
No.
6/71
7/71
8/71
9/71
10/73
11/71
12/73
13/73
14/73
15/73
16/73
17/71
18/71
19/71
2O/71
21/71
22/73
21/71
24/73
IS/71
2t/73
27/73
28/73
2»/71
3O/73
31/73
32/73
33/73
34/73
35/73
36/73
37/73
38/73
Liiacstone
Particle
Cycle l.l*e- Site Range
Ho. Fuel stone (u)
1 Aamay(2.3tS) Pfizer 6OO-3175
2 " Calcite "
3 "
4 "
5 "
6 "
7 "
8 "
9 " "
1O " " "
11 "
12 *
13 -
14 "
15 '
16 "
17
1* ' "
1» "
20 '
21 " "
22
23 '
24 "
25 "
26 '
27 "
ia * ™ "
26
39 "
3O ™ "
31
32
33 "
21O
231
204
207
203
191
210
269
259
255
181
191
1»3
216
213
199
207
180
181
179
179
18O
183
190
179
179
179
179
181
2O1
176
Superficial
Total Gas
U/«in>
792
672
669
687
683
639
680
743
662
698
679
683
696
692
689
697
654
648
639
631
655
660
669
674
647
621
(29
680
659
648
665
b41
(»/«ec)
2.24
1.84
1.84
1.91
2.08
1.81
1.84
2.10
1.81
1.90
1.84
1.94
1.97
1.96
1.95
.1.98
1.79
1.79
1.77
1.76
1.83
1.88
1.91
1.91
1.81
1.74
1.76
1.93
1.88
1.84
1.88
1.82
Air
34.6
26.8
30.1
30.5
30.9
3O.6
29.7
25.3
23. «
25.1
34.3
33.0
33. 1
29.5
29.7
32.2
29. 0
31.0
32.3
32.4
31.7
33.6
33. «
12.5
11.1
12.4
32.8
35.0
33.3
29.6
30.7
3O.O
Bed depth
(centinetres)
Start
48.0
/ 46.0
43.9
40.6
36.6
-
38.9
37.1
51.6
51.8
42.7
44.2
38.1
30.5
33.8
34.6
48.3
42.2
48.1
49.0
45.2
47.2
46.2
47.0
44.2
4O.1
42.4
42.4
42.9
49.3
49. 3
48. 5
End
47.2
38.9
36.6
36.6
35. 1
-
32.3
31.5
46. 5
38.1
43.4
38.6
35.8
29.0
30.5
21.2
43.4
42.7
45.5
46.5
44.2
41.7
44.2
46. 0
41.1
37.3
42.2
43.4
41.7
41.7
41.7
39.1
Avereqe
Bed Bed Te«J>
Specific (Absorption!
Gravity CO
O.71
0.75
0.83
0.77
0.68
-
0.71
0.68
0.76
0.83
0.79
0.79
0.71
0.79
-
-
0.82
0.83
0.79
0.79
0.83
0.92
0.83
0.81
0.83
O.92
0.88
0.88
0.92
0.92
0.92
0.96
880
945
845
855
920
880
875
840
835
835
880
880
880
875
885
840
850
855
860
865
885
89O
885
880
870
865
880
885
885
880
880
(180
nu. Bed
Top
IKeeen.)
(•C|
975
1015
1025
1O35
1O40
1O4O
1040
1055
101S
1O10
10OD
102O
1025
1035
1O4O
1040
1O4O
955
995
1015
1010
1030
1030
1030
1035
1010
1O2O
1015
1029
1025
1030
1030
1025
Duration nake-up
of Height
Absorption (liAestonej
(•in.)
-------
CYCLIC TEST COHDITIOMS AMD S.R.E.'S (TEST 5-D I
C/i
Run Cyc le
Ho. He. Fuel
82/73
83/73
84/73
85/73
86/73
• 7/73
•8/73
89/73
90/73
91/73
92/73
93/73
94/73
95/73
96/73
97/73
98/73
99/73
3
4
5
6
7
8
9
10 "
11
12 "
13
14
15
16
17
18
la "
Limestone
Particle
Lime- Size Range. Fuel Rate
atone \> g/»in
[ SCR 1359 600-3175 198
194
227
• 24O
220
• 22O
240
230
250
23}
• • 272
• " 194
" • 185
" " 2O1
" 207
• " 207
• " 217
269
Superficial
Total Ga>
, Air* velocity.
1/min m/»ec
700
700
700
67O
683
709
683
67O
671
660
648
698
<8O
7O4
656
6O8
574
661
676
1.95
1.96
1.98
1.9O
1.91
2.00
1.93
1.9O
1.88
1.85
1.99
1.89
1.98
1.85
1.72
1.6O
1.88
1.88
t stolch.
Air
31.3
31.8
27. 2
24.7
27.5
28.5
25.2
25.8
23.7
24.6
22.7
3O.9
33.7
28.9
26.0
29.5
26.9
22.2
Bed Depth
centiffet re-
Start End
43
41
41
39
47
40
34
5O
46
SO
44
46
46
46
46
44
44
41
41
41
41
41
39
44
. 4O
35
48
47
47
46
47
45
46
47
46
4O
42
41
Bed
Specific
Gravity
0.83
O.83
0.83
0.87
0.81
0.86
0.93
0-79
0.80
0.83
0.87
0.83
0.83
0.83
0.83
0.87
0.92
0.87
O.86
Averaoe »»» »ed Duration Hake-up
Bed ".•£. Te^, of Heistt Cyclone
(Ab.orptlon) , <*e*en>. M>.orpti«l. (Ll«e«tol>e> . Ou»t,
-c
-------
Table N-8 CYCLIC TEST CONDITIONS FOR HIGH SULPHUR PITCH (TEST 6-C)
1
Ul
-4
00
1
Run No.
130/73
131/73
132/73
133/73
134/73
135/73
136/73
137/73
138/73
139/73
14O/73
141/73
142/73
143/73
144/73
145/73
146/73
147/73
148/73
149/73
Stone
Cycle Size Rang*
No. Stone Microns
1 BCR 1359 600-3175
2 '
3
4 '
5
6
7 " "
8
9
10
11
12
13
14
15
16
17
18
19
20
Fuel
Rate
g/min
208
201
175
156
136
156
156
157
182
169
182
188
156
149
157
170
162
149
135
158
Total
Air
I/Bin
490
548
575
524
513
517
528
510
52O
521
485
491
553
530
52O
510
525
533
533
539
Superficial %
Gas Vel. Stoic
ft/sec Air
1.34
1.49
1.55
1.43
1.40
1.40
1.43
1.4O
1.43
1.43
1.34
1.34
1.52
1.46
1.43
1.40
1.43
1.46
1.46
1.46
23.3
27.0
32.0
32.9
36.9
32.5
33.1
31.8
27.9
30.2
26. 0
25.5
34.7
34.8
32.3
29.4
31.6
35.0
38.6
33.4
Bed Pressure
Drop
(inches
Start
42
43
43
46
46
48
47
48
43
43
44
46
46
46
48
47
48
47
46
46
HjO) (Al
End
43
43
42
46
47
47
47
50
41
43
44
48
46
46
48
47
48
46
46
46
Average
Bed Temp
bsorption
•C
870
870
900
88O
900
89O
910
9OO
890
880
90O
880
895
9OO
9OO
91O
915
9OO
9OO
910
Max Bed Duration
Temp of
) (Regen) Absorption
•C Mins
1O3O 35
1040
1035
1O40
1020
1O40 "
1030
1030
1050
1030 "
1O5O
1050
1050
1010
1040
1030
1030
1030
1030
1025
Make-up
Height
(Limestone) SRE
g/cycle %
74.5
1030 7O.9
1300 84.5
79.4
82.5
76.8
76.8
81.0
75.0
8O.O
69.5
71.0
82.0
84.0
79.0
76. 0
82.0
84.0
83.0
82.5
-------
Table N-9 KEROSENE COMBUSTION (TESTS 1-A, 2-A, 3-A.4-A
Stone;
BCR 1691
Denbighshire
BCR 1359
Pfizec Calcite
Bed Bed Cyclone Bed Bed
Tim*, Depth, Specific Dust, Temp. , Depth,
hr Metres Gravity g 'C Metres
0 .59 0.75 - 875 .53
H .47 O.79 170 90O .49
1 .40 0.79 920 880 -SO
14 .39 0.75 1005 855 .49
2 .37 0.77 390 89O .47
2fc .32 O.77 42O 8 SO .46
f 3 .31 O.77 29O 893 .45
V£> 3lf .30 O.77 28O 900 .46
1 4 - - -44
41s - - ...
5 - -
5* - -
6 - - - -
Bed
Specific
Gravity
0.75
0.79
0.75
0.75
O.79
O.77
0.79
0.79
0.82
-
-
-
-
Cyclone
Dust,
g
-
280
135
125
80
85
35
40
30
-
-
-
-
Bed
Temp.,
•C
87O
87O
865
870
870
885
890
8 SO
860
-
-
-
-
Bed
Depth,
Metres
.58
.55
.52
.53
.51
.51
.49
.49
.49
.49
.51
.52
.50
Bed
Specific
Gravity
0.75
0.79
0.83
O.79
0.83
O.83
0.83
0.88
0.86
O.83
O.82
O.80
0.82
Cyclone
Dust,
g
-
90
70
60
50
87
55
40
30
30
27
23
35
'Bed
Temp- .
•C
850
842
860
860
865
865
872
87O
880
880
860
86O
860
Bed
, Depth ,
Metres
O.51
0.50
0.48
O.48
O.43
0.42
0.42
0.43
0.4O
0.4O
0.39
Bed
Specific
Gravity
O.
O.
O.
0.
0.
O.
0.
0.
0.
0.
0.
75
79
79
73
79
78
79
75
79
79
79
Cyc lone
Oust,
g
-
303
210
268
221
185
90
96
143
90
91
Bed
Temp.,
•C
870
865
82O
865
89O
859
853
845
880
855
859
-------
Table N-10 KEROSENE COMBUSTION (TESTS 1-B, 2-B)
1
en
oo
O
1
Stone:
Time,
hr
O
*
1
1*
2
2*5
3
3*
4
4%
5
5*5
6
BCR 1691
Bed
Depth,
Metres
.55
.52
.55
5.1
.49
.46
.47
.46
.47
.45
.45
.44
.43
Bed
Specific
Gravity
0.73
0.73
0.71
0.75
0.75
O.75
O.76
0.76
0.75
0.77
O.80
0.82
0.80
Cyclone
Dust,
g
0
317
55
235
38O
130
80
75
75
60
50
50
30
Bed
Temp. ,
"C
1020
1O8O
1065
1078
1080
107O
1058
1054
1078
1090
1075
1065
1065
Bed
Depth,
Metres
.50
.45
.44
.39
-
.42
.39
.39
.39
.38
.39
.39
.39
Denb ighshire
Bed
Specific
Gravity
0.83
0.90
0.91
1.00
-
0.91
0.98
l.OO
l.OO
1.01
l.OO
l.OO
l.OO
Cyclone
Dust,
g
-
270
90
27
-
47
18
20
14
12
11
10
6
Bed
Temp. ,
°C
1010
1015
1080
1050
-
1O8O
1O8O
1060
1050
1050
1050
1O6O
1080
-------
Table N-ll. FUEL OIL COMBUSTION (TESTS 1-C, 2-C)
Stone:
BCR 1691
Denbighshire
Pfizer Calcite
t/l
OO
Tine,
hr
0
d
1
1%
2
2
-------
Table N-12. FUEL OIL GASIFICATION (TESTS 1-D, 2-D, 3-B)
Stone:
BCR 1691
Denbighshire
BCR 1359
1
en
00
to
1
Time,
hr
O
h
1
1%
2
2*
3
3%
4
4*1
5 -
5*
6
Bed
Depth,
Metres
O.55
0.56
O.49
0.5O
0.52
O.5O
0.48
0.48
0.49
0.49
O.46
O.46
0.4S
Bed
Specific
Gravity
0.79
0.75
O.83
O.82
0.82
0.79
0.82
0.83
0.83
O.83
0.87
0.87
0.87
Cyclone
Dust,
9
-
40
395
135
95
1O
100
70
70
86
75
7O
55
Bed
Temp. ,
•c
868
86O
8«O
85O
86O
855
855
855
850
862
870
870
867
Fuel
Rate,
g/min
-
170
178
170
197
200
204
211
239
221
231
185
216
Bed
Depth,
Metres
0.58
0.49
0.43
O.41
0.41
O.41
0.41
O.9O
0.48
0.41
O.4O
0.39
O.4O
Bed
Specific
Gravity
0.75
0.82
0.87
0.92
0.92
0.92
O.92
0.92
0.92
0.92
0.96
0.96
0.96
Cyclone
Dust,
9
-
49O
290
150
60
130
40
75
33
60
50
60
35
Bed
Temp. ,
•C
900
850
860
850
848
862
862
850
840
850
860
865
870
Fuel
Rate'
g/min
-
178
204
178
208
206
211
221
242
238
224
221
212
Bed
Depth,
Metres
0.56
0.52
0.52
0.49
O.48
0.49
0.42
0.46
0.47
O.46
0.5O
0.47
0.47
Bed
Specific
Gravity
O.75
0.79
0.79
0.83
0.88
0.83
0.83
0.88
0.88
0.89
0.92
0.96
0.96
Cyclone
Dust,
g
-
180
127
90
90
60
67
62
60
60
50
52
-
Bed
Temp. ,
•C
93O
835
86O
853
868
86O
868
870
86O
860
860
86O
860
Fuel
Rate
g/min
-
173
180
192
204
204
214
221
221
242
234
234
234
-------
Table N-13. KEROSENE COMBUSTION ON CYCLED BED (TESTS 1-F, 2-F)
1
LTI
CO
OJ
1
Stone:
Time,
hr
0
*
1
1%
2
2%
3
3%
4
4*
5
5*
6
BCR 1691
Bed
Depth ,
Metres
0.58
0.51
0.49
0.48
0.46
0.45
0.45
0.44
0.44
0.42
0.41
0.40
0.40
Bed
Specific
Gravity
0.75
0.83
0.83
0.83
0.83
l
0.83
0.83
0.82
0.82
0.83
0.83
0.83
0.79
Cyclone
Dust,
g
-
24O
175
170
280
>
1OO
40
230
100
4O
40
100
140
Bed
Temp. ,
°C
90O
880
815
830
8OO
80O
85O
820
770
850
850
850
870
Bed
Depth ,
Metres
0.47
0.46
O.45
0.45
0.45
0.45
0.46
0.46
0.44
0.43
0.44
0.43
0.42
Denbighshire
Bed
Specific
Gravity
0.96
1.0
1.0
1.0
1.02
1.0
l.O
1.0
1.03
1.04
1.04
1.04
1.04
Cyclone
Dust,
g
-
18
10
12
8
12
10
10
8
5
8
7
7
Bed
Temp. ,
•c
850
830
843
853
860
870
872
862
865
868
875
880
880
-------
Table N-14. GASIFICATIOM OF HEAVY RESIDUAL FUEL OILS
I
Ol
FRESH BED TEST RESULTS (TESTS 5-A, 5-B
Run:
Time,
Hrs
0
*
1
l«l
2
2*
3
3%
4
Run No 1O1/73
Aauay vacuum Bottoms
Totals Carbon Fuel/Air Bed
« wt. % wt. Ratio Temp.,
Bed Bed * Stoich *C
23 82O
_
2.25 2.85 * 860
— — ** •-
4.76 11.42 " 850
.
5.83 15.7 " 875
_
7.62 20.7 - 860
Run No 102/73
Amuay Residual Fuel Oil
Cyclone
Oust,
9
-
-
150
100
103
-
257
-
284
Total Carbon Fuel/Air Bed
Sulphur % wt. Ratio Temp.,
twt Bed Bed t Stoich *C
27 880
_
2.30 1.00 ' 860
-
4.31 0.30 " 880
_
6.53 1.58 ' 86O
_
8.14 2.27 ' 860
Cyclone
Dust,
g
-
138
96
112
114
124
9O
136
68
, 5-D)
Run No 1O4/73
Amuay Vacuum Bottoms with 2*.5t02
Total Carbon Fuel/Air Bed
Sulphur % wt Ratio Temp. ,
%wt Bed Bed * Stoich 'C
26.7 9OO
_ _ * —
3.36 O.97 " 900
-
5.73 7.18 " 92O
.
7.83 12.4 " 940
7.89 11.3
«
Cyclone
Dust,
9
-
213
119
223
-
296
263
220
-
-------
Run:
Run No 1O7/73
Table N-15 . GASIFICATION OF HEAVY RESIDUAL FUEL OILS
FRESH BED TEST RESULTS^(TESTS 5-C, 6-A, .6-B)
Run No 108/73
Run No 109/73
High Sulphur Pitch
1
Ui
00
m
1
Time,
Hrs
0
%
1
1%
2
2i|
3
3>|
4
Total
Sulphur
%wt Bed
_
^.
1.94
—
3.76
-
5.82
-
8.02
Carbon
% wt.
Bed
_
_
0.23
_.
0.24
-
1.62
-
3.27
Fuel/Air
Ratio
% Stoich
28.1
-
-
It
it
"
n
"
H
Bed
Temp. ,
°C
940
-
940
_
95O
-
95O
-
94O
Cyclone
Dust,
g
-
526
241
300
265
311
288
281
272
Total
Sulphur
%wt Bed
-
-
3.59
-
4.96
6.29
6.9O
Carbon Fuel /Air Bed
» wt. Ratio Temp. ,
Bed * Stoich «C
24.5 86O
_
12.39 " 890
_ " —
17.82 " 905
" 910
91O
Cyclone
Dust,
g
-
88
70
13O
140
215
115
Total Carbon Fuel/Air Bed cyclone
Sulphur % wt. Ratio Temp., Dust,
*wt Bed Bed % Stoich °C g
31.6
_ 89O 12O
2.91 8.31 " 860 ISO
4.73 11.76 " 880 75
5.82 13.02 " 900 175
-------
APPENDIX O
OIL AND LIMESTONE
OIL
The oil used in the present work have been heavy fuel oils
from Venezuelan crudes obtained from Amuay refinery of
Creole Petroleum Co. One supply, obtained in drums direct
from Amuay has been used in batch unit tests. A second
supply from bulk storage in the U.K. has been used in pilot
plant work. An additional supply of very heavy residue has
been obtained for batch unit studies which have not yet
begun. This oil/ also from Amuay, is vacuum pipe still
bottoms produced when ordinary atmospheric pipe still
bottoms is further distilled to give a vacuum gas oil which
can be hydrofined to give a reduced sulphur fuel oil.
Chemical and physical inspection results of these three oils
are listed in Table O-l.
LIMESTONE
Pilot plant runs have employed U.S. limestone BCR 1691 and
a U.K. limestone from Denbighshire. Batch unit work has
employed these two stones as well as U.S. stone BCR 1359.
Two additional U.S. stones have been recieved. They are
Tymochtee Dolomite and a limetstone selected by New England
Electric System: Pfizer Calcite. This was selected because
of its proximity to the proposed demonstration unit. Chemical
inspections of all the stones are listed in Table 0-2.
Additional analyses on fuel oil and limestone used in Runs
6 and 7 is given in Appendix J, Tables I and II.
- 586 -
-------
Table 0-1
Properties of
en
oo
Property
Specific Gravity
Kinematic Viscosity
CS at 14O deg. F
21O deg. F
28O deg. F
35O deg. F
4OO deg. G
Carbon % by wt.
Hydrogen "
Sulphur
Nitrogen
Conradson Carbon "
Asphaltenes
Vanadium ppm
Nickel
Sodium
it
Iron
CAFB
Amuay
Batch Unit
Tests
0.957
201
41.4
85.9
11.3
2.35
0.35
11.6
7.1
366
43
36
3
Test Fuel
Oils
Amuay Pilot Plant Tests
1/12/71
0.955
221
39.3
85.6
11.4
2.48
0.26
10.9
4.8
345
40
35
4
14/3/73
O.960
40.3
85.8
11.6
2.42
0.09
11.1
5.3
300
65
37
-
26/3/73
0.960
254
45.6
85.3
11.3
2.43
0-35
10.8
6.O
315
41
38
3
Vacuum
Bottoms
1.015
318O
321
71
240
85.7
10.3
2.95
0.63
17.4
6.9
53O
6
9
108
High
Sulphur
Pitch
1.101
-
84.5
8.7
5.4
0.64
33.0
15.0
155
65
17
15
-------
Table O-2
Chemical Properties of Test Limestones
Ul
oo
oo
Limestone Composition
Stone :
Component
CaO % by wt.
MgO *
Si02
Fe203
co2
S (Total)
Vanadium ppm
Sodium "
Nickel
BCR 1691
45.6
3.35
13.65
0.35
2.80
35.7
0.44
41
219
40
BCR 1359
54.1
O.6O
0.75
O.09
0.31
44.0
0.12
50
< 20
30
Denbighshire
5 5.. 2
0.30
0.68
O.10
0.25
43.4
< O.O5
26
59
21
tee Calcite
Dolomite
31.1
20.9
3.1
0.4
1.13
43.6
0.13
25
175
10
55.0
O.6
0.8
O.O9
0.3
43.2
0.03
< 20
250
50
-------
TECHNICAL REPORT DATA
(Please read Inunctions on the reverse before completing)
I. REPORT NO.
EPA-650/2-74-109
3. RECIPIENT'S ACCESSION-NO.
4. TITLE AND SUBTITLE
for Sulphur Removal During Gasification of Heavy
Fuel Oil- -Second Phase
5. REPORT DATE
November 1974
6. PERFORMING ORGANIZATION CODE
7 AUTHOR(S)J.W.T.Craig, G.L.Johnes, Z.Kowszun,
G. Moss, J. H. Taylor, and D. E. Tisdall
8. PERFORMING ORGANIZATION REPORT NO.
9. PERFORMING ORGANIZATION NAME AND ADDRESS
Esso Research Centre
Abingdon, Berkshire
England
10. PROGRAM ELEMENT NO.
1AB013: ROAP 21ADD-BE
11. CONTRACT/GRANT NO.
68-02-0300
12. SPONSORING AGENCY NAME AND ADDRESS
EPA, Office of Research and Development
NERC-RTP, Control Systems Laboratory
Research Triangle Park, NC 27711
13. TYPE OF REPORT AND PERIOD COVERED
Second Phase July72-May73
14. SPONSORING AGENCY CODE
15. SUPPLEMENTARY NOTES
. ABSTRACT
repOr£ (jos cribes the second phase of studies on the CAFB process for
desulfurizing gasification of heavy fuel oil in a bed of hot lime. The first continuous
pilot plant test with U.S. limestone BCR 1691 experienced local stone sintering and
severe production of sticky dust during startup. Batch tests confirmed that BCR 1691
produced more dust than the purer Denbighshire or U.S. BCR 1359 stones. With BCR
1691, 10 times more dust was produced during kerosene combustion at 870C than
during gasification/regeneration. The continuous pilot plant was modified to improve
operability under dusty conditions: 332 gasification hours were spent in a second run
with Denbighshire and BCR 1691 stones in six operating periods , the longest being 109
hours. Sulfur removal efficiency was comparable for the two stones , ranging from
60 to 95%. Regenerator performance was less satisfactory than in earlier tests. A
poor sulfur material balance indicates need for improved analytical procedures.
Total CAFB development through a large demonstration test will probably take
about 6-7 years and require $3,320,000 in engineering effort.
KEY WORDS AND DOCUMENT ANALYSIS
DESCRIPTORS
b.lDENTIFIERS/OPEN ENDED TERMS
. COSATI Field/Group
Air Pollution
Regeneration
(Engineering)
Sulfur
Desulfurization
Gasification
Fuel Oil
Calcium Oxides
Limestone
Air Pollution Control
Stationary Sources
CAFB Process
Chemically Active
Fluidized Bed
Fluidized Lime Bed
FUP! Oil
13B
08G
vy
CUB I
07B
07A, 07D
13H
21D
18. DISTRIBUTION STATEMENT
Unlimited
19. SECURITY CLASS (ThisReport)
Unclassified
21. NO. OF PAGES
589
20. SECURITY CLASS (This page)
Unclassified
22. PRICE
EPA Form 2220-1 (9-73)
- 589 -
------- |