-------
59
Since its initial operation in 1973, the TCA scrubber on Unit 1 has
undergone a number of modifications. These include removing all finned
tube steam reheat coils (1975), installing additional soot blowers
(1974), replacing the original Fiberglass reinforced plastic (FRP) mist
eliminators with stainless steel (1976), and adding turning vanes to the
ESP outlet and scrubber inlet ductwork (1974).
Future changes to the scrubber will depend on mist eliminator tests
being conducted for the Unit 3 scrubber. A decision will be made on
whether to replace all of the mist eliminator sections with a newer
design or to expand present reheat capacity.
Unit 3
A model 6700 TCA scrubber was installed on Unit 3 in 1975. It has
three parallel sections: sections 3A and 3C each handle 20% of the gas,
and section 3B handles the remaining 60%. The sections receive gas flow
from two common parallel scrubber booster fans but are designed to
operate independently. Section 3A and 3C each have one recirculating
slurry pump (19,000 1pm or 5,000 gpm) while section 3B has three recircu-
lating slurry pumps (57,000 1pm or 15,000 gpm). Particle collection
efficiency is 93% with three scrubbing stages and an L/G of 7.4 1/m
(55 gal/1,000 ft3). Direct stack reheat to 85ฐC (185ฐF) is provided by in-
line steam coils arranged in three tube bundles equipped with soot
blowers to remove deposits from tube surfaces.
Since its initial operation in 1972, the TCA scrubber has gone
through a number of modifications. These include replacing all finned
tube steam reheat coils with plain coils (1975-76), installing additional
soot blowers (1973), and replacing the original FRP mist eliminators
with stainless steel (1977). In August, 1977, the Company replaced the
stainless steel mist eliminators in Sections 3A and 3C with plastic
assemblies manufactured by Heil (Heilex Model EB-4) and Hunters (Euro-
form Model 271), respectively. The Company will observe the mist removal
-------
60
efficiency of these assemblies and, based upon the test outcome, will
decide whether to replace all of the mist eliminator sections with one
of these newer designs or to expand present scrubber reheat capacity.
Unit 4
Four model 4200 TCA scrubbers were installed on Unit 4 in 1974. The
scrubbers, designated as sections 4A, 4B, 4C, and 4D, were each designed
to handle 25% of the gas flow. Each section receives gas flow from an
individual scrubber booster fan. There are three recirculating pumps
per section designed to provide a total recirculating flow of 80,000 1pm
(21,000 gpm). The design particle collection efficiency is 97% with
three scrubbing stages and an L/G of 8.3 1/m3 (62 gal/1,000 ft3).
Indirect stack gas reheat to 79ฐC (175ฐF) is provided by mixing the
scrubbed gas with heated ambient air in a venturi type mixing chamber.
Since its initial operation in 1974, the Unit 4 TCA scrubber has
gone through a number of modifications. These include adding a second
reheat air fan to each scrubber reheat system (1976) and installing
outlet damper purge air systems (1976).
OPERATION AND MAINTENANCE
The operation of the scrubbers is, for the most part, monitored
and controlled from panels located in the respective boiler unit control
rooms. The data that is monitored is shown in Table 12. The essential
areas of control are the gas flows, recirculating slurry, mist elimina-
tors and reheaters.
Normal scrubber operation requires all scrubber sections in service
on Units 1 and 3, and three of four sections in service on Unit 4. When
one of the smaller sections of the scrubbers on Units 1 and 3 require
repair, the Company treats all the gas flow from that unit in the
-------
SCRUBBER LOG
CHEROKEE STATION
PUBLIC SERVICE COMPANJ OF COLORADO
61
UNIT
NO 1
I
I 12-B I B-4 ' J-lTT
NO 3
I
NO 4
SHIFT
12-8 I 8-d I 0-1
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CHEROKEE STATION
SCRUBBER LOG
DAY.
.DATE.
.19.
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62
remaining scrubber sections. If the larger scrubber section on Units 1
or 3 is removed from service, part of the gas is bypassed to the stack.
The gas flow to the scrubber is automatically controlled by main-
taining the inlet scrubber booster fan pressure to within proper limits
(e.g., -1.0 to -2.5 cm W.G.). When the inlet pressure deviates from
this range, the fan dampers are automatically adjusted accordingly. No
attempt is made to shift scrubber sections in or out of service during
increasing or decreasing load conditions. When the booster fan control
is unable to keep the fan inlet pressure within the proper range (a
situation which exists when there is a high pressure drop across the
scrubber) the stack bypass damper is activated and gas flow is bypassed
to the stack. Pressure and pressure drop information are monitored and
recorded once per shift.
The rec'.rculating slurry flow is manually controlled by maintaining
the slurry pump motor amps within a predetermined operating range (e.g.,
11-16 amps for recirculating slurry pumps on Unit 4). This is accomplished
by adjusting the slurry pump discharge valve. No attempt is made to
vary the slurry flow with gas flow or unit load. When the slurry pump
motor amps are low (out of the control range), the Company tries to back-
flush the line. If no improvement is noted, a Station Service Request
(SSR) is prepared to initiate proper corrective action. When a slurry
pump is taken out of service the affected scrubber section is not
removed from service. In the case of scrubber sections 1A, 3A and 3C
which have one recirculating slurry pump each, the Company maintains a
limited flow of water in the section by running the mist eliminator wash.
The blowdown of recirculating slurry is dictated by the scrubber
water balance requirements. During each shift, an operator takes a sam-
ple of the slurry and measures settleable solids and pH. If the settle-
able solids concentration is higher than is to be allowed (i.e. 3.0 weight
%), adjustments are -"'- *- +*!*ป fresh water inlet rate and/or an SSR is
initiated to check the drawoff lines and other potential trouble areas.
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63
The operation of the mist eliminator wash system varies between
units. On Units 1 and 3, a manual wash system has been installed. Once
each shift, an operator sequentially opens the mist eliminator wash
header valves and each header is left on for two minutes. On Unit 4, an
automatic wash system sequentially operates each wash header for a
period of three (3) minutes each shift. The timing of the mist eliminator
wash system can be adjusted according to changes in operating conditions.
The control of the reheat system is based on maintaining the exit
gas temperature within proper limits. The operator adjusts the set
point on a pressure control valve which supplies steam to the reheat
steam coils. At full load conditions, the control valves are set at
P
maximum design values [21 kg/cm (300 psi) for Units 1 and 3; 28-35
kg/cm2 (400-500 psi) for Unit 4]. At low loads, the operator reduces
the set point of the pressure control valve accordingly.
Maintenance practices that are reported in effect for the TCA
scrubbers can be divided into two categores: daily or routine inspection
checks conducted when the scrubbers are in operation; and major and/or
minor repairs conducted when the scrubber is taken out of service.
Moreover, the differences between the Unit 4 scrubbers and those on
Units 1 and 3 must also be recognized. Since the Unit 4 scrubbers are
operated with three of the four equal-size modules in service, it is
possible to rotate the operating modules every 3 to 4 months so that
frequent internal maintenance can be performed. It is also possible to
switch modules when one of the operating modules is performing poorly.
This approach is not possible on Units 1 and 3.
Daily maintenance checks are performed on the slurry and recircula-
tion pumps. These are checked for leaky packings, oil level, oil leaks,
abnormal noise and vibration. Other pieces of equipment are monitored
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64
by Plant Operations and include data collected from instrument read-
outs. When instrument values are outside of the appropriate range,
Operations personnel initiate a Station Service Request (SSR), which
details an equipment or instrument problem that is to be checked and
repaired by Maintenance. Then, depending on the urgency of the SSR,
immediate action is taken or action is scheduled for the next scrubber
outage.
The bulk of the scrubber maintenance work is conducted during major
or minor outages. In this case, a major outage is defined as a boiler
unit outage exceeding four to six weeks, whereas a minor outage is any
other time the scrubber is brought out of service. Besides repairing
SSR items, the scrubber is inspected for ball wear and pluggage by
solids. The balls are inspected and weighed periodically. If a repre-
sentative number of balls (100 balls) have lost more than 20% of the
weight of an equivalent number of new balls, then the balls are replaced
with new balls. If there are a lot of broken balls or balls have migrated,
then new balls are added. Solids pluggage is removed with a jackhammer,
by manual washing, or through chiseling by hand as required. In general,
if anything is found during an inspection that reduces efficiency, i.e.,
ball migration or missing spray nozzles, repairs are made at that time.
During a major outage, a complete overhaul program is undertaken.
The guillotine gates are inspected, shafts are repacked and any item
that is not working properly is repaired as time permits. The reheat
coils (Units 1 and 3) are cleaned and tested for leaks. The duct work
is inspected and cleaned. The recirculation system is inspected for
wear, pluggage and failures. The mist eliminators and mist eliminator
spray nozzles are inspected and cleaned. The vertical dividers and grid
bars are inspected and repaired or replaced as necessary. The pre-
saturator area and hoppers are cleaned and the pump screens are checked
and repaired. The presaturator nozzles are inspected and replaced as
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65
needed. The scrubber booster fans are checked and repaired as neces-
sary. The fan bearing oil is changed and new shaft seals are installed.
All soot blowers (Units 1 and 3) are inspected and checked for proper
operation.
SCRUBBER INSPECTIONS
Unit 3
An inspection of the Unit 3 scrubber was conducted on August 5,
1977. The unit had been shut down for a scheduled outage in which a
scrubber overhaul was planned. The last previous major scrubber over-
haul had occurred in August - September, 1976. The results of the
inspection were as follows.
Presatwc'atov
The presaturator had large solids deposits in the area of the
wet-dry interface. Section C had the largest accumulation of solids
forming a layer as much as two meters deep. Sections A and B had solids
accumulations of about one meter in depth. There were also solid for-
mations projecting from the top spray nozzles. The solids on both the
floor and ceiling of the presaturator formed a very hard deposit. The
solid-cone presaturator spray nozzles that were inspected did not appear
to be plugged or covered with solids but in some cases solids had
accumulated around the nozzle, possibly restricting the spray coverage.
Scrubber Swnps
The scrubber sumps had accumulated solids at the bottom but the
solids level did not appear to reach the spray pump intake lines. All
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66
the pump intake lines have screens. Broken balls had accumulated on
most of the screens, but none of the screens were completely plugged.
Packing Stages
There was evidence throughout the mobile ball sections of ball
migration and poor gas flow distribution. This typically appeared as
maldistribution of balls and deposition of solids on the bottom of the
packing stages. Generally, it appeared that the majority of the gas.
tended to flow from the presaturator section up the "back side" of the
scrubber. (The "back side" of the scrubber is the east side or side
opposite the presaturator section.) This could have resulted from the
high velocities resulting from restriction in the presaturator section
In section 3A, the ball migration problem was very evident, since
it was possible to look up from the eastside of the scrubber sump to the
mist eliminator blades because of ball migration. In all three stages,
the layer of balls (nominally at 20-30 cm depth) varied from zero thick-
ness for the east one-third of the stage to as much as 1 m near the west
end of the scrubber. There did not appear to be any significant solids
buildup in the 3A section.
Section 3B showed a less consistent pattern of ball migration. In
the first stage (which was made up of twelve wire-grid compartments), two
of the compartments on the east side and one compartment on the west
side had less than one layer of balls, whereas two middle compartments
had 0.5 m and 1 m ball depths. A couple of breaks were noted in the
grids separating the far east and middle compartments where ball migra-
tion could occur. The second stage had a uniform distribution of
balls. The third stage of this section, however, had poor distribution.
The south one-third of the stage had less than one layer of balls and
the depth of the balls became progressively deeper toward the southwest
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67
corner of the scrubber stage. The only significant solids buildup noted
was on the bottom of the first stage. Scaled areas covering about one-
fourth and one-sixteenth of the cross-sectional area were seen in the
middle of the bottom stage and of the northwest corner of the first
grid, respectively.
Section 3C had the most significant solids accumulations. Approxi-
mately three-fourths of the bottom of the first stage was scaled over.
A large mass (0.5-1 m diameter) of a very hard deposit of accumulated
solids and balls was found in the east compartment of this stage. The
bottom of the west compartment on the second stage was also scaled over.
The third stage did not have significant solid deposits. Ball migration
problems were not as evident in this section. The first stage had less
balls on the east side of each compartment, varying by as much as 10 to
20 cm (4 to 8 in), while the second and third stages had reasonably good
ball distribution.
The physical condition of the ball grids and scrubber liner was
reasonably good. The most prevalent ball types found were a solid black
rubber ball and a hollow green plastic ball. Less than 5% of the balls
appeared to be broken or grossly worn. The support grids were intact
with the exception of those noted above. However, it was observed that
at the point of contact, overlapping grid wires apparently were "cutting"
into one another. In many cases for the first stage, as much as 0.5 to
1 cm wear was observed. This is apparently due to vibration and movement
of the strands when the scrubber is in service. The rubber scrubber
liner, although found to be in fairly good condition overall, had some
bubbles or blisters where the liner had popped off the steel underneath,
especially in section 3B stage 1 and section 3C stage 2. There were
also a couple of areas in section 3B stage 1 and section 3C stage 1
where pieces of the liner had come off, exposing the underlying metal.
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68
Recirculating Slurry Pumps and Nozzles
The impellers of the slurry pumps were inspected from the suction
side of the pump which had been opened for each pump. The rubber-
covered impellers seemed to be intact and in good condition. Inspection
was also made of the recirculating nozzles. Several of the nozzles were
plugged: 7 of 14 in section 3A, 9 of 42 in section 3B and 7 of 14 in
section 3C. The material causing the pluggage was mostly 0.6 to 1.0 cm
rubber liner, possibly eroded from the recirculating lines. The ori-
fices of several of the recirculating slurry nozzles were measured and
did not show significant wear.
Mist Eliminator'
The mist eliminator area was observed to be in very good condition
with the exception of wash nozzle which had broken loose from its header.
The chevrons, which were 316 SS, had very little solids deposit and did
not show any gross signs of pitting or corroding. The alignment of the
mist eliminator blades was also good.
Reheater Area
At the time of the inspection, only sections 3A and 3C had reheater
coils in place. The coils were reasonably clean. There was a thin
solids layer (<2 to 4 mm) on most of the coils with significant deposits
(1 to 2 cm) found only on the bottom of the tubes in the lowest tube
bundles. No pitting of the 316 tubes was observed. There was evidence
of severe rusting and corrosion of the ducting which surrounds the
coils. In section 3B, in which the reheater coils had been absent,
there were several holes in the reheat duct area caused by excessive
corrosion.
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69
Ductuork and Dampers
The ductwork downstream of the scrubbers, the isolation dampers,
and the bypass ductwork were inspected. The downstream ductwork was
badly rusted for all three sections and large pieces of the corroded
carbon steel ductwork could be easily pulled off by hand. The ductwork
was set and in section 3C there was a wet solids accumulation as deep as
10 cm throughout. The inlet guillotine gates were closed and from a
limited inspection appeared to be in good condition. The outlet dampers
were rusted and corroded. None appeared capable of providing a tight
seal and the bottom louver blade in 3C was mired in solids in a half
open position (the other blades of the damper were closed). The bypass
ductwork was found to have extensive, very hard deposits. The buildups
were as much as 1 m deep throughout.
The Company representative who accompanied NEIC personnel on the
inspections was knowledgeable of the problems present and how they
would be fixed.
A follow-up inspection of the Unit 3 scrubber was conducted on
August 24, 1977. The purpose of the inspection was to determine the
thoroughness of the scrubber overhaul in light of the problems noted
from the previous inspection and to inspect the new mist eliminator
assemblies that were to be installed in sections 3A and 3C.
The solids in the presaturator and scrubber sump had been thoroughly
removed. The pump intake lines were clear. The recirculating slurry
nozzles had been cleaned. The new mist eliminator assemblies were in
place and appeared to be properly installed. The reheat ductwork in 3B
had had a plate installed to cover the corroded areas. The bypass
ductwork area had been thoroughly cleaned out.
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70
The ball sections had not been cleaned and balls had not been
redistributed or added, although the Company representative stated that
this would be done prior to startup. The areas where the scrubber liner
had fallen off were not repatched.
Unit 4
A very limited inspection of the C section of the Unit 4 scrubber
was conducted on August 14, 1977. The boiler unit had been brought .down
to inspect a leak in the boiler tubes. The only areas open for inspec-
tion were the presaturator area and the scrubber sump.
A layer of soft solids approximately 0.5 m deep was present on the
presaturator floor. The presaturator nozzles, however, were clear and,
in general, the presaturator area was in good shape. A sma'il section
(approximately 2 ft square) of rubber liner had come loose from one wall
just downstream of the presaturator spray nozzles. The scrubber sump on
the north side had its pump intake screen clogged with balls. The other
two sumps were filled with water and their intake screens were not
visible. The bottom of the first stage of the scrubber had significant
solids buildup across approximately 15% of the cross-section. These
deposits were noted on the presaturator side of the scrubber.
UPSET REPORTING
As discussed in the previous section, Public Service Company of
Colorado has reported day-to-day malfunctions of the particulate control
equipment. The data generated in these upset reports were used to
review scrubber availability and the major sources of scrubber mal-
functions.
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71
Availability
Availability, as reported by PSCC, is defined as:
.. ..,.+ Scrubber hours operation - hours boiler burning 100% gas
Availability - Boiler nours operation - hours boiler burning 100% gas
A distinction is also made as to how "scrubber hours operation" is
defined for each unit. For the Unit 1 and 3 scrubbers, the scrubber
is considered to be operating when all sections of the scrubbers are in
service. For the Unit 4 scrubber, the scrubber is considered to be
operating if 3 of the 4 sections are in service.
Figure 9 shows cumulative 12-month availabilities for the scrubbers
at Cherokee Station based on the above definitions. The data include
the time period from when the scrubbers were initially put in operation
until April 1977, after which time this recording method was discon-
tinued.
Various trends can be identified from Figure 9. All scrubbers
appear to go through an initial start-up/shake-down period when scrubber
availabilities are low. As the initial problems were solved, availa-
bilities gradually increased until a maximum point (>90% availability)
was reached, typically 30 to 40 months after initial startup. There-
after, the curves appear to take on more individual pattern reflecting
the differences between units. The availability curve for Unit 3 began
to sharply decrease after reaching the maximum, while the curve for
Unit 4 has constantly remained above 90% availability. Unit 1 scrubber
availability was not plotted for any significant period after reaching
its maximum point but, because of its similarities to Unit 3 (i.e., no
spare scrubber sections, limited weather enclosure, direct reheat,
etc.), it would be expected to experience a dropoff in availability
similar to that of Unit 3.
-------
100
90
80 !
n
| 70
U
,60
3
3
>
J
* 50
c
3
H
]40
g30
5
20
10
LEGEND
CHEROKEE UNIT 1
CHEROKEE UNIT 3
CHEROKEE UNIT 4
UU...1
: j ' ' J _L^ i '
: ; ; i" i ";
ro
MONTHS AFTER SCRUBBER STARTUP
Figure 9: Cumulative Twelve Month Scrubber
Availabilities, Cherokee Station, Public Service
Company of Colorado
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73
Table 13 shows the average availability for each year of scrubber
operation. The overall averages for scrubber availabilities are:
Unit 1 65%
Unit 3 63%
Unit 4 84%
Equipment Upset Data
The upset reports provide information on equipment component mal-
functions but the reports are not sufficiently comprehensive to allow
a definitive scrubber equipment component evaluation to be made. The
data do not show causes of failures nor do they allow differentiation
between primary and secondary effects, i.e. whether breakdowns were
caused by the equipment component itself or were associated with dis-
turbances from other components. Furthermore, a number of months of
data were either not available or too imcomplete to be included in this
analysis. Finally, it was impossible to properly distribute downtime to
equipment when more than one component required repairs during a given
outage. As a result of these factors, only a broad definition of
scrubber related problems is possible.
Table 14 shows estimates of relative contributions of various
scrubber subsystems to scrubber downtime for each unit. The estimates
are expressed as a percentage of the reduction in scrubber availability
due to major areas for each 12-month period. The estimates are based
on scrubber upset reports prepared by PSCC.
The most illuminating observation from Table 14 is that there are
significant differences in problems causing outages between the various
units. Major problem areas for the Units 1 and 3 scrubbers are the
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74
Table 13
SUMMARY OF PERCENT SCRUBBER AVAILABILITY*
BY YEAR OF OPERATION
CHEROKEE STATION
PUBLIC SERVICE COMPANY OF COLORADO
Year
1
2
3
4
5
**
Average
+ All/llTrrlvf
Unit 1
52
48
82
90ft
NA
65
7 . Scrubber
Unit 3
47
81
64
49
80ft
63
hrs operation -
Unit 4
80
83
*
93
NA
NA
84
hrs boiler burning 100% gas
tt Based on 7 months data.
* Based on 6 months data.
** Average is calculated by averaging the availabilities from each year.
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75
Table 14
MAJOR REPORTED PROBLEM AREAS CAUSING SCRUBBER l-lALFUHCTIOflSa
CHEROKEE STATION
PUBLIC SERVICE COMPANY OF COLORADO
Unit I
Umt 3
Unit 4
Year 1 Oct. 1973-Sep. 1974
Data not available
Year 2 Oct. 1974-Sep. 1975 c
Reheater 51%
Scrubber, Internals 21%
Booster Fans 21%
Recirculating Slurry 3%e
Other 6%
Year 3 Oct. 1975-Sep. 1976
Recirculating Slurry 58%
Scrubber, Internals 33%
Reheater 6%
Other 3%
Year 4 Oct. 1976-Sep. 1977
Recirculating Pumps 67%
Scrubber, Internals 27%
Recirculating Slurry 4%
Booster Fans 1%
Other 1%
Year 5 NA
Oct. 1972-Sep. 1973
Data not available
(Oct. 1973-Sep, 1974)
Data not available
(Oct. 1974-Sep. 1975)c
Reheater 42%
Scrubber, Internals 13%
Recirculating Pumps 4%
Recirculating Slurry 2%
Other 39%
(Oct. 1975-Sep. 1975)
Reheaters 64%
Booster Fans 14%
Scrubber, Internals 12%
Recirailating Slurry 9%
Other 1%
(Oct. 1976-Nov. 1977)'
Recirculating Slurry 65%
Reheater 21S
Recirculating Pumps 12%
Other 2%
Nov. 1974-Oct. 1975
Booster Fans 92%
Isolation Dampers 3%
Reheater 3%
Other 2%
Nov. 1975-Oct. 1976'
Booster Fans 90%
Reheater 1%
Other 9%
Nov. 1976-0ct.l977 c
Booster Fans 79%
Recirculating Slurry 13%
Isolation Dampers 3%
Recirculating Pumps 2%
Reheater 1%
Other 2%
NA
NA
a All data are estimates of scrubber equipment downtime taken from PSCC upset reports expressed as a percent
of annual scrubber dountime.
b Based on 5 months reported data.
c Based on 6 months reported data.
d "Scrubber, internals" includes the scrubber grids, scrubber liner mobile balls and recirculatinn slurry
nozzles.
e "Recirculating slurry" system includes the slurry drauoff, scrubber slurry hopper and recirculating slurry
piping.
1 Based on 7 months reported data.
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76
reheaters, scrubber internals, recirculating slurry system and recircu-
lating slurry pumps. The major problem areas for the Unit 4 scrubbers
are the scrubber booster fans.
The major problem areas for the Units 1 and 3 scrubbers in apparent
order of importances are: reheaters, scrubber internals, recirculating
slurry system and recirculating slurry pumps. The reheaters have
resulted from corrosion and pluggage of the in-line steam coils. Typi-
cal problems with the scrubber internals include inspection, repair, and
replacement of scrubber grids, scrubber liner, and mobile balls.
Difficulties in the recirculating slurry system include repairing leaky
recirculating slurry piping, unplugging the slurry drawoff line and
removing slurry buildups in the scrubber hoppers. The recirculating
slurry pump problems appear to mainly be due to bearing, packing and
motor difficulties.
The major upset problems encountered in the Unit 4 scrubbers are
almost exclusively due to scrubber booster fan malfunctions, and lack of
other major problems can be attributed to improved design features. The
scrubber booster fans are air foil fans which have been highly subject
to erosion from fly ash carried over from the ESP's. Unit 4 is operated
with one module as a spare, therefore maintenance to scrubber internals,
recirculation pumps, piping, etc. can be routinely scheduled. Further-
more as critical scrubber problems occur and require repair, the affected
scrubber section can be replaced with the spare section with relatively
short-term opacity excursions. Unit 4 scrubbers also have indirect
reheaters which are less subject to corrosion and plugging than are
direct in-line heaters. Unit 4 scrubbers are totally enclosed, thus
preventing significant freezing problems.
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77
EVALUATION OF SCRUBBER PERFORMANCE AND OPERATION
The performance of the TCA scrubber were evaluated using the
operating data collected during the study period, and data from pre-
vious stack tests, efficiency tests, etc. Prior to this analysis,
Meteorological Research, Inc.1* prepared an analysis of the particulate
removal performance of the Cherokee Unit 3 scrubber. Their results
and the results of this study are discussed in this section.
Table 15 shows the particulate removal performance data for the
scrubbers on each unit based on recent stack tests and published
reports. For each unit, a comparison is made between design values and
actual values of grain loadings, efficiencies and powerplant load.
The scrubber particulate loadings are important in evaluating com-
pliance with particulate regulations. In reviewing the data, it is
noted that, with one exception, the outlet grain loadings show compliance
with the process weight regulation requiring particulate emissions to
be less than 0.1 Ib per MM Btu heat input. The one exception is the
o
average outlet loading of 0.14 g/std m (0.06 gr/SCF) taken from data
reported by MRI for November 1974. This loading may have been in
excess of 0.1 Ib per MM Btu, but could not be determined since the
circumstances under which this data was taken could not be evaluated.
Opacity meter data [Table 15] and visible emission observations are
also indications of outlet particulate loadings. However, it is signi-
ficant to note that small particles contribute proportionately more to
high opacities than to high particulate loadings. As a result, opacity
and outlet particulate loadings are not directly related. The wide
variations in opacity data are important because they reflect the wide
fluctuations in scrubber operations.
-------
Table 15
ACTUAL AND DESIGN PARTICULATE REMOVAL DATA FOR TCA SCRUBBERS
CHEROKEE STATION
PUBLIC SERVICE COMPANY OF COLORADO3
oo
Unit
Unit No. Oper. Scrubber Inlet
Load Scrubber Participate Loading
MW Sections g/std m*gr/ft3
Scrubber Outlet Particulate Visible
Particulate Loading Removal Eff. Emiss. Qbserv.c
g/std m*gr/ft3Ib/mm Btu
Opacity
Unit 1
Design
Actual
Unit 3
Design
Actual
Actual
Actual
Unit 4
Design
Actual
(PSCC)
(PSCCt
(MRD;
(MRI)f
(PSCC)
115
94
170
163
160
160
375
345
1-
3
3
1.80
_9
0.69
0.87
1.58
1.60
_ h
0.80
0.30
0.38
0.69
0.70
0.046
0.076
0.046
0.069
0.14
0.097
0.046
0.047
0.02
0.03
0.02
0.04
0.06
0.04
0.021
0.02
0.069
0.069
97.5
93
84
94
97
5-60
0.050
5-40
a
Data in this table is taken from references, 13 2 and 4. Actual data taken by Public Service Co. of
Colorado is shown as (PSCC) and actual data taken by Meteorological Rearch3 Inc. is shown as (MRI).
b Particulate removal efficiencies are not shown for actual PSCC data since inlet and outlet particulate
loadings were not taken under similar conditions.
c Visible emission observations are from data taken by EPA-NEIC during July-August^ 1977 and represent a
wide range of operating conditions. These data are included in Appendices A and B.
d Sections 1A (Unit 1) 3 3C (Unit 3) and 4D (Unit 4) were not in service during these tests.
e This data is based on tests reported in reference 4 for the dates 11/7/74 - 11/19/74.
f This data is based on tests reported in reference 4 for the dates 12/10/74 - 12/12/74.
g Actual PSCC data incomplete.
h Actual PSCC data not reported because recent tests not available.
-------
79
The data in Table 15 show that the actual scrubber outlet loadings
for Units 1 and 3 exceed the design values. To investigate the cause
and significance of this observation, it is necessary to consider some
of the factors which affect the outlet particle loading, i.e., the
scrubber inlet particulate loading and the scrubber's particulate re-
moval efficiency. The outlet particulate loading is related to the
inlet loading and scrubber efficiency as follows:
Outlet particle loading = Inlet particle loading x (1 - efficiency)
The inlet loading to the scrubber is dependent on a number of fac-
tors including: the coal that is being fired, the boiler operation, the
mechanical collector/ESP operation and addition of conditioning agent.
With such a variety of factors, it is not unexpected that there are
reported differences in inlet particulate loadings between units and
between the same unit at different time periods. A more significant
observation is that actual scrubber inlet particulate loadings can and
do significantly exceed design values. Although the scrubbers have some
inherent capability for removing excess particulate, it is not known how
large an excess can be handled or for how long. In Section V, infor-
mation reported in PSCC upset reports has shown violations of the 20%
opacity standards (as measured by the opacity meters) due to ESP mal-
functions. Since these violations occurred when the scrubber was in
service, it must be concluded that the scrubber outlet particulate
loading can exceed standards even when the scrubber is not in an upset
condition. Therefore, it is important that the mechanical collector/ESP
efficiency be improved and maintained at optimum conditions. Operation
of the ESP's at 40 to 60% efficiency is not acceptable.
Very limited scrubber efficiency data is available for the scrubber
installations at Cherokee. From data developed from other mobile bed
-------
80
contactors it is expected that particle collection efficiency will be
dependent on gas flow, liquid flows, and state of motion of the mobile
contactor beds as indicated by pressure drop.7 In addition, it is
important to recognize that nonuniformities such as gas flow imbalances,
liquid flow imbalances, solids pluggage, etc. play an important role in
determining the particulate removal efficiency of large-scale scrubber
installations. These are reviewed in the following discussion.
The only available efficiency data for the Cherokee Station is
presented in the MRI study. In their initial set of tests (average
particulate removal efficiency of 84%), they found flow and outlet
particle loading imbalances between sections of the Unit 3 scrubber.
To correct this, the scrubber was shut down, some of the mobile bed
packing was redistributed and a clogged reheater was partially cleaned.
Efficiency tests conducted subsequent to this shutdown showed improved
efficiency (average efficiencies of 94%). MRI also analyzed the scrubber
outlet particulate and found a high concentration of soluble components
indicating that liquid entrainment was occurring to a significant degree.
MRI concluded that the scrubber performance data they obtained reflected
specific scrubber conditons and that general scrubber particulate removal
efficiency correlations could not be developed from the data.
The scrubber operating data accumulated during the study also
relected a wide range of operating conditions. Table 16 shows gas flow,
liquid flow and pressure drop data taken during the study. The data
was taken from instrumentation located in the boiler control rooms.
The gas flow data are shown in terms of scrubber booster fan motor
amps. These data present little basis for analysis since fan motor amps
are also a function of pressure drop and fan/motor efficiencies. It does
appear, however, from data taken for Unit 4, that the gas flow is
-------
Table 16
SCRUBBER OPERATING DATA
CHEROKEE STATION
PUBLIC SERVICE COMPANY OF COLORADO
Unit
Unit 1
Section
Section
Unit 3
Section
Section
Section
Unit 4
Section
Section
Section
No. of
Observa-
tions
42
A
B
4
A
B
C
44
B
C
D
Scrubber
Load Booster Fan
flW Ampsf
84-119 130-150(A)
125-153(6}
110-152 190-220(A)
180-220(8)
253-360
200-250
220-240
225-245
Recirculating
Slurry Pump
1
0-24
21-22
20-24
25
NO
12.5-13
11-13
11-14
2
Amps
NAft
20-28.5
NA
22
NA
15-16
0-14
11.5-14
3
NA
0-24
NA
20-21
NA
12-14
12.5-15
12-14
Pressure Drop
System
Unit
24-50
24-50
27-34
27-34
27-34
NO
23-58
18-38
Mobile
Beds
cm
7-23
10-24
15-23
14-18
8-10
10-29
11-38
10-25
Mist Reheater
Elim.
H20
2-13
1-7
0-1
3-4
1-2
2-3
1-5
5-7
5-28
2-14
2-3
N0f++
1-3
NO
1-5
NO
t Fans on Unit 1 and 3 scrubbers provide common flow to the scrubbers.
tt Not applicable.
ttt NO = indicating meter not in operation.
-------
82
reasonably well distributed between the three scrubbing sectons. No
observation can be made for flow distribution between sections in the
Unit 1 and Unit 3 scrubbers since these do not have individual fans for
each section.
More conclusive data on gas flows are shown in Table 17. These
data were taken from recent stack tests performed for the units and are
compared against design values. It is noted that in all cases of
reduced scrubber section operation the superficial scrubber velocity is
4.8 to 5.8 meters per second (mps) as compared to a design maximum of 40
mps. Furthermore, even under "normal operation" for Units 3 and 4 (4.7
and 4.8 mps superficial velocity, respectively), the design maximum
velocity is exceeded. Although this has apparently not affected compliance
with the process weight regulation, it can result in improper bed fluid-
ization and high liquid entrainment. Above superficial gas velocities
of about 4.0 mps, it has been shown that pressure drops and bed expansion
increase to the point where mobile spheres are held up at the top of the
retaining grids.7 Liquid entrainment also increases when gas velocities
increase, and can become severe when the velocities are 4 mps and higher.8
The distribution of gas flow between scrubber sections on Units 1
and 3 could not be determined from operating data accumulated during
this study. However, field measurements made by MRI during 1974 do
show the magnitude of typical gas flow variations. Figures 10 and 11
show sets of gas velocity profiles taken before and after the Unit 3
scrubber had been cleaned, balls redistributed, and reheater partially
cleaned. Theoretically, the profiles should be reasonably close to
one another, but as shown in the curves, the average velocities between
sections can vary by as much as 3 to 1. This type of variation indicates
that even if the bulk scrubber gas velocity (as calculated in Table 17)
is within proper design limits, the velocities within each section may
be outside the range required for proper operation of the beds. Over-
all particulate removal may be reduced and liquid entrainment can be
significantly increased.
-------
83
Table 17
DESIGN VS ACTUAL VALUES OF SCRUBBER SUPERFICIAL VELOCITIES
AND LIQUID-TO-GAS RATIOS (L/G)
CHEROKEE STATION .
PUBLIC SERVICE COMPANY OF COLORADO
ft
Actual Conditions Scrubber Operation Reduced Scrubber Operation
Unit 1
Design
Actual
Unit 3
Design
Actual
Unit 4
Design
Actual
m3/hr
730,000
730,000
850,000
1,000,000
2,200,000
2,100,000
ft3/min
430,000
430,000
500,000
590,000
1,300,000
1,200,000
Velocity
(mps)
4.0**
4.0**
4.0
4.7**
4.0
3.7
L/G
(1/m3)
7.7
7.7**
7.0
5.9**
7.9
8.6
Velocity
(mps)
4.0
5.4
4.0
5.8
4.0
4.8**
L/G
(1/m3)
7.7
4.3
7.0
3.9
7.9
4.8**
t Data is representative of scrubber conditions (52ฐC or 125CF) at full load
and is taken from references 1, 2 and 4. Design flowrates are design
maximums. Actual flowrates are calculated from representative stack
test and precipitator outlet data.
tt "'Pull scrubber operation" assumes all scrubber sections in service.
* "Reduced scrubber operation" assumes one section of the scrubber out of
service as follows: 1A in unit 13 SA or 3C in unit 33 any one section
in unit 4.
** Indicates normal operation for scrubber unit.
-------
84
Wall
Duct A
Duct B
O Duct C
VELOCITY, m/sec, STACK CONDITIONS
Figure 10
Velocity Profiles for Outlet Ducts Before Cleaning
Cherokee Unit'3 Scrubber (11/18/74)
Cherokee Station
Public Service Company of Colorado1*
-------
85
Wall
0.5
1.0
H
U
Q
ฃ
n
K
H
OH
W
Q
1.5
2.0
Wall
D Duct A
X Duct F
O Duct C
77ฐ C
66'C
66'C
10 15 20
VELOCITY, m/sec, STACK CONDITIONS
25
Figure 11. Velocity Profile for Outlet Ducts of
Unit 3 Scrubber (12/10/74) After Cleaning
Cherokee Station
Public Service Company of Colorado1*
-------
86
Table 13 also shows variations in liquid-to-gas (L/G) ratios under
various full load conditions. Once again, there is a significant de-
parture from design L/G values under "normal" scrubber operations (Units
3 and 4 only) and under "reduced" scrubber operations (all Units). In
general, decreasing the L/G ratio (with constant gas velocity and
pressure drop) is expected to reduce particulate removal; however, no
precise quantitative relationships could be developed from available
literature to indicate the expected decrease in particulate removal.
More significant observations of liquid flow rate variation are-
shown in Table 12. For sixteen of the observations (6 days) on Unit 1,
the pump in the single-pump scrubber section (Section 1A) was not in
service. Obviously, under these conditions, the particulate removal in
that section of the scrubber is very much reduced. Furthermore, pro-
longed exposure of the scrubber internals to these conditions (where
scrubber temperatures approach 90ฐC (200ฐF) even with some water in-
troduced continuously through the mist eliminator nozzles, may cause the
rubber liner to blister and creep and cause deformation of the plastic
sphere.
Minor instances of 1 to 2 day's duration were also observed where
one of the three pumps in a scrubbing section was out of service. These
cases are not as critical since scrubber internals are not severely
affected and overall particulate removal may not be significantly re-
duced depending on AP and gas velocity values.
When the current to a given recirculating pump motor is below
levels that, by experience, indicate pump or line problems (11 amps on
Unit 4 pumps and 20 amps on Units 1 and 3 pumps) an immediate investi-
gation is reportedly made. Typically the problem is one of a plugged
suction line and backflushing is initiated. However, as noted in the
Unit 3 scrubber inspection, plugging of recirculating spray nozzles may
also be occurring and this cannot be detected without an internal
-------
87
scrubber inspection. Besides reducing scrubber liquid flow, plugged
nozzles can cause liquid maldistribution and, if extreme, can lead to
improper fluidization of the scrubber bed.
The pressure drop UP) across the mobile bed could be expected to
be a primary indicator of the particulate removal performance and of
the conditions within the bed such as fluidization, gas channeling,
etc. Particulate removal performance as a function of AP was studied
by MRI with a limited amount of data. Table 18 shows the results of
that study in which no correlation could be found between particulate
removal efficiency and pressure drop. Instead, as noted previously,
MRI attributed the variations in particulate removal efficiency to
numerous operating factors in existence at the time of their tests.
The pressure drop recorded across the mobile beds should also
provide an indication of the conditions within those beds. It was
stated by the Company that pressure drops of less than 15 to 20 cm (6 to
8 in) water column (W.C.) at full load are an indication that gas
channeling is occurring within the scrubber. At the other extreme, the
manufacturer's operating limitations1 state that the scrubber should not
be operated above 30 to 35 cm (12 to 14 in) W.C. due to bed expansion
and problems caused by mobile packing held up against the retaining
grid. This latter condition can result in flooding within the scrubber.
Instances when pressure drops were outside of the lower and upper limits
are shown in Table 19.
Interpretation of the pressure drop data in Table 19 is not straight
forward. The data indicate, that channeling was occurring in Unit 1
(sections 1A and IB) and Unit 3 (section 3C), whereas flooding may have
been occurring in Unit 4 (section 4A). However, to put the data in
proper perspective, it is necessary to compare the Unit 3 pressure drop
data with subsequent inspection observations that were made when the
scrubber was taken out of service. These inspections indicated that the
-------
Table 18
SCRUBBER COLLECTION EFFICIENCIES "*- UNIT 3
CHEROKEE STATION
PUBLIC SERVICE COMPANY OF COLORADO
03
OO
DATE
11/20
11/Z:
12/10*
12/11
12/12
I.CKD
mw
166
164
157
160
160
oa
I'crecnt
3.6
3.4
3.4
3.0
2.6
Oi.TLLT
GAS PLOW-
AC! UAL
ma/hr
a
a
9.47 x 10*
10.2 x 10*
8.78 x 10*
sr.ci io\ A
ฃI>
SYSTEJ*
cmiljO
41
39
36
38
38
"4s,
cmHjO
9.9
9.6
15.2
14.7
14.7
cmHjO
0.76
0.76
1.7
1.5
1.8
EFF.
ND
ND
96.3
96.4
79.6
sr.ci :o\ u
AP
SYSTEfc
cmHjO
45
43
41
42
44
AP
3LD
cmH,O
25
18
20.8
22.1
22.9
iP
MIST
riLLMIN.
cmlljO
2.5
1.8
2.5
3.2
2. S
EFF.
84.7
89.9
92.6
93.2
93. I
SKCIIOV C
.i P
SYSTEM
cmJIjO
46
44
41
44
46
1
^P
BED
cnilljO
24
20
IS. 5
22.4
24.1
iP
M:ST
ELIMIN*.
emHjO
8.3
5.1
3.8
2.5
3.8
EFF.
SO
ND
86.9
96.7
92.1
a Full velocity traverses were not taKen.
b The control room data were incomplete. Interviews^ data from other days and the log
were used to supplement available information.
-------
89
Table 19
PRESSURE DROP FOR SCRUBBER MOBILE BED SECTIONS
DURING FULL LOAD CONDITIONS
CHEROKEE STATION
PUBLIC SERVICE COMPANY OF COLORADO
Unit
Total No. of
Load Observations
No. of
Observations
AP bed <15 cm W.C.
No. of
Observations
AP bed >35 cm W.C.
Unit 1
Section A
Section B
Unit 3
Section A
Section B
Section C
Unit 4
Section B
Section C
Section D
t Includes
tt Includes
-115 MW
-145 MW
-350 MW
10 observations
2 observations
22
22
3
3
3
26
26
26tt
18T
12
0
0
3
5
0
2
when 1A1 recirculation
when section 4D AP bed
0
0
0
0
0
0
16
1
pump was out of service.
instrumentation was out of
service.
-------
90
low pressure drop in section 3C was due to low flow resulting from heavy
solids accumulation in both the presaturator and scrubber bed. On the
other hand, the inspection revealed that gas flow channeling was exist-
ing in other sections (especially section 3A) but was not indicated from
pressure drop instrumentation. This may have occurred because the
sections were forced to handle higher than design gas flow rates.
It should also be recognized that the type of packing also influ-
ences the pressure drop. Studies performed at West Virginia Univer-
sity1 showed that pressure drop was, in part, dependent on the physical
properties of the packing (e.g. shape, weight, size). With the dif-
ferent types of balls being used in the scrubbers and the added problems
of ball migration, interpretation of pressure drop measurements is
further complicated.
The operating data collected during the scrubber performance
evaluation is not conclusive. It is evident that the scrubber sections
are typically operated at gas velocities, liquid flowrates and pressure
drops outside of design ranges. It is also evident that scrubber in-
strumentation does not consistently indicate when internal scrubber
problems, such as ball migration, gas flow channelling, and solids
deposition, are occurring.
EVALUATION OF SCRUBBER SYSTEM RELIABILITY
From the previous discussion, it is apparent that even if 100%
of the gas is flowing through the TCA scrubber, the scrubber may not be
capable of meeting applicable particulate regulations. Scrubber avail-
ability is, therefore, not an adequate measure of scrubber performance.
Instead, it is necessary to introduce the term "reliability". Relia-
bility, as used in this report, will be defined as: the percent of time
the boiler is on-line that the particulate control systems are operating
and meeting applicable particulate regulations.
-------
91
To adequately review reliability in light of the existing Cherokee
Station scrubber operation, it is important to consider the individual
equipment components which appear to have the largest impact on scrubber
reliability. In their May 1975 study, which appears as an appendix to
the MRI evaluation,** Steams-Roger, Inc. identified components present-
ing major maintenance problems for the Unit 3 scrubber. Those problems
and problems which appear to contribute significantly to current scrubber
reliability deficiencies are shown in Table 20. As can be seen, most
of the problems identified in the earlier study are still present. The
major reliability problem components are reviewed individually in the
following discussion.
Wear of Mobile Bed Contactors
Prior to this survey, PSCC had extensively tested balls of varying
compositions and designs and indicated that the ball wear problem was
their major maintenance item. As the balls were exposed to turbulent
conditions in the scrubber, they would wear out, break apart, dimple,
etc. The fluidization of the bed was disturbed and balls migrated to
cause flow channeling in the scrubber and wear problems in other com-
ponents of the scrubber system. Obviously, the particulate removal
ability of the scrubber was then reduced and the scrubber had to be
taken out of service to redistribute balls, replace balls, etc.
PSCC has evaluated balls made of a number of different materials
including polyethylene, polypropylene and thermoplastic rubber but has
now stated that a polyethylene ball of unique construction provides what
they consider to be adequate resistance to wear. (A ball providing
"adequate" resistance to wear is expected to have a useful life of about
one year.) The ball is a hollow green-colored sphere manufactured by
Puget Sound Trading Co. The unique feature of the ball is that it has
crimps or indentations which tend to give it greater strength. Report-
edly, the indentations also cause the ball to acquire a characteristic
-------
Table 20
PROBLEM AREAS IDENTIFIED IN SCRUBBER RELIABILITY EVALUATIONS
CHEROKEE STATION
PUBLIC SERVICE COMPANY OF COLORADO
Major Scrubber Problem Areas
Identified in May 1975 Study,
Unit 3
'Unit 1
Scrubber Reliability Problem Areas
of Major Significance Identified in NEIC Study
Unit 3
Unit 4
VO
Breakage of mobile bed
contactors
Migration of mobile
bed contactors
Guillotine dampers
Recirculation pumps
Reheater Section
Rubber lined piping
Presaturator buildup
Mist eliminators
Stack damper interlock
system
Recirculation system venturi
flow meter
Scrubber booster fan bearings
Weather related problems
Wear of mobile bed
contactors
Migration of mobile
bed contactors
Isolation dampers
Recirculation pumps
Reheater Section
Recirculation piping
and nozzle
Presaturator buildup
Mist eliminators
Wear of mobile bed
contactors
Migration of mobile
bed contactors
Isolation dampers
Recirculation pumps
Reheater Section
Recirculation piping
and nozzle
Presaturator buildup
Mist eliminators
Wear of mobile bed
contactors
Migration of mobile
bed contactors
Isolation dampers
Reheater Section
Recirculation piping
and nozzle
Mist eliminators
Scrubber booster fan Scrubber booster fan Scrubber booster fan
Weather related problems Weather related problems
Outlet ductwork Outlet ductwork Outlet ductwork
-------
93
spin. This, in turn, results in ball wear in one or two spots rather
than at a number of points from which a ball can break into pieces.
The green polyethylene ball is still not ideal and PSCC indicates
that they continue to search for an improved design. When the green
ball does wear it fills with scrubber slurry and falls to the bottom
of the stage. Proper turbulent contact is then difficult to maintain
within the scrubber if a significant number of the balls are worn.
No matter what ball is used, operating the scrubber with large
flow imbalances is still a significant problem. Certain portions of
the scrubber are exposed to high ball wear whereas other areas may see
minimum or negligible ball wear. A possible solution to this ball wear
problem may be to repl ice the mobile packing with stationary packing.
PSCC does not consider this alternative to be feasible, mainly because
they feel that Universal Oil Products will no longer stand behind the
scrubbers if such a radical change is made.
The use of an open-type packing has been investigated in tests
performed by Southern California Edison at the Mohave Generating Station
in 1974 and 1975.9 A polygrid "egg crate" packing was used consisting
of plastic grids 3 cm thick with 5 cm square openings, stacked to a
depth of 43 cm in each of three stages. The scrubbing liquid was a
limestone slurry. The results of the study indicated that high par-
ticulate removal i.e. >90%, could be achieved [Figure 12]. Although a
limited number of tests were conducted and problems with scaling were
not evaluated, the use of open packing appears to be very promising.
Migration of Mobile Bed Contactors
The other major ball problem affecting scrubber operation is ball
migration. Balls migrate due to ball wear, ball breakage, and breaks
-------
94
100%
95%
38
_f
>
O 90%
ui
tt
Ul
85%
oc
80%
75%
"I I I
INLET GRAIN LOADING: 0.10 gr/scf
VERTICAL
TCA MODULE
4 STAGES
18.000 GPM
I
VERTICAL
PPA MODULE
3 STAGES
27,000 GPM
100 200 300 400
FLUE GAS FLOWRATE. scfm x 103
500
Figure 12. Particulate Removal Tests for a
Vertical Scrubber Using Different Types of Packing
-------
95
in the partitions separating ball compartments. As in the case of the
ball wear problem described previously, scrubber particulate removal
performance decreases and downtime for repair increases.
PSCC has reduced some of the problems brought about by ball migra-
tion by placing screens on the suctions to the recirculation pumps.
Previously, balls would circulate through the system, cut pump linings,
plug nozzles, etc. The problem of migration within the scrubber still
remains, however. The migration problem is not always readily deter-
mined from pressure drop data as was noted in previous discussions.
Obviously, frequent inspections and replacement of worn grids and balls
is an important factor in minimizing ball migration between compart-
ments. Another potential solution is to replace the mobile packing
with stationary packing.
Isolation Dampers
On-going isolation damper problems have plagued the TCA scrubbers
since these began operation. Inlet dampers accumulate ash deposits and
are exposed to varying gas temperatures and conditions. Outlet dampers
accumulate sludge deposits from scrubber carryover and are exposed to
varying gas temperatures and conditions depending on scrubber mist
eliminator and reheater operation. As a result, the gates and lower
blades warp; they are difficult to operate and are hampered by gas
leaks into drive trains, couplings, etc.
The best available approach to minimizing the isolation damper
problem is to improve the damper operating conditions. At the inlet,
this would involve reducing particulate loading by optimizing ESP per-
formance as much as possible. At the scrubber outlet, it would be
necessary to minimize flow imbalance and liquid entrainment problems
and improve the operation of the reheaters. In addition, it may be
-------
96
necessary to routinely exercise isolation dampers similar to what is
currently being done for the stack bypass dampers.
Recirculation Pumps
Although a number of major pump problems had been solved during
initial scrubber operations, problems with recirculation pump operation
still remain. However, in view of the rugged duty to which these pumps
are subjected, e.g. fly ash slurry, almost continuous operation, etc.,
some problems must be expected. It may not be possible to significantly
improve the existing slurry pump operation. Major maintenance and
repair areas include pump motors, bearings and packing.
The major problem, as noted previously, is where a scrubber section
has only one recirculating pump (sections 1A, 3A, and 3C}. When the
pump is inoperable, either the scrubber section must be taken out of
service or it must be operated with no recirculating slurry. The former
condition results in reduced scrubber capacity whereas the latter causes
severly limited particulate removal performance and possible exposure of
scrubber internals to adverse high temperature conditions. Possible
solutions to this problem are to install additional pumps on the existing
one-pump sections or to pipe all the recirculating slurry pumps for a
given unit to a single manifold which would feed all the scrubber sections
of that unit.
Reheater Section
There have been numerous problems in the operation of the stack
gas reheaters. The direct reheaters on Units 1 and 3 have been subject
to pluggage due to carryover from the scrubbers and to corrosion. The
reheaters on all three units have been plagued with an inability to
provide sufficient reheat of scrubbed gases.
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97
When the direct reheaters on Units 1 and 3 get plugged, the scrub-
ber section is taken out of service for cleaning. The plugging is
thought to be caused by water droplets being carried over from the
scrubber. When the droplets evaporate, solids which were originally
present as dissolved and suspended solids deposit on the in-line coils.
Early efforts by PSCC to minimize plugging of reheaters included in-
creasing the number of soot blowers and replacing finned-tube coils with
bare-tube coils. Since then PSCC has also attempted to improve mist
eliminator performance by installing new mist eliminator designs, but
these tests have not yet been evaluated by PSCC. With the gas and
liquid flow imbalance problems previously noted, it is questionable
whether the new mist eliminator designs will significantly improve the
reheater plugging problem. The soundest approach to solving the plug-
ging problem appears to be replacing the direct reheaters with indirect
reheaters similar to those now in operation on Unit 4.
Corrosion of the in-line reheater tubes has led to tube failure and
resulting scrubber down time for repair. Corrosion is believed to
generally occur under the deposits that form on the tubes.10 Originally
the tubes at Cherokee were carbon steel, but after repeated tube failure,
PSCC replaced the carbon steel tubes with 316 SS. These have proven to
be successful thus far. However, it has been pointed out in other
powerplant scrubber applications10 that 316 SS is highly vulnerable to
failure to chloride stress corrosion. A long term solution, as noted
above, would be to use indirect reheaters.
The available reheat from the reheater system has been found to be
insufficient (less than design) in all three scrubbers. When the reheat
is not adequate, condensation occurs in the outlet ductwork and stack,
causing corrosion of these components. Also, inadequate reheat results
in droplet carryover problems, giving false opacity meter readings.
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98
The cause of inadequate reheat appears to be due to solids build-
up on in-line reheater tubes (Units 1 and 3), corrosion of in-line
reheater tubes (Units 1 and 3), and presence of liquid entrainment
levels (all units). PSCC has reportedly conducted heat balances for the
stack gas reheaters. These have shown that much more heat from the
steam was used than is necessary for the sensible heat required to
provide the stack gas temperatures that are actually measured. Table
21, which shows design and actual observed stack gas exit temperatures,
indicates that average stack exit temperatures ranged from 46 to 67ฐC
(115 to 153ฐF) or about 12 to 40ฐC (20 to 70ฐF) less than design values.
Solid buildup on in-line reheater tubes affects reheat by reducing
the heat transfer from the tubes to the stack gas while corrosion of in-
line reheater tubes not only restricts heat transfer but also can cause
leaks resulting in loss of steam. Improvement of these problems was
discussed previously. The problem of high Iquid entrainment requires
improvement in the mist eliminator collection efficiency and/or gas flow
distribution in the scrubber.
Recirculation Piping and Nozzles
The recirculating slurry contains fly ash which is composed of very
abrasive constituents such as silicon dioxide (Si{L) and aluminum tri-
oxide (AUO.,). As a result, the rubber lining of the pipes is subject
to highly erosive conditions, especially where the slurry impinges
directly on the liner. This occurs at pipe bends of Y's and locations
where the rubber liner is incorrectly applied and surface liner irregu-
larities are formed. When the liner begins to erode, chunks of rubber
are broken away and lodge in recirulating slurry nozzles. As the liner
continues to erode at a given location, accelerated wear takes place and
an increasingly irregular surface is formed. When the liner has been
stripped from the pipe, the underlying metal is also exposed to corro-
sive attack from the low pH slurry.
-------
99
Table 21
DESIGN AND ACTUAL VALUES* OF STACK GAS TEMPERATURES
CHEROKEE STATION
PUBLIC SERVICE COMPAM OF COLORADO
Parameter
Design
Actual (Average)
Section A
Section B
Section C
Section D
Unit
ฐC
93
*
53
62
**
NA
NA
1
ฐF
200
128
144
NA
NA
Unit
ฐC
85
46
65
48
NA
3
ฐF
185
115
149
118
NA
Unit
ฐC
79
50
56
64
67
4
ฐF
175
N0ft
132
148
153
t Actual values are those noted in July-August 1977 observations
from instrumentation reading.
tt NO = Not in operation during July-August observation period.
* Unit 13 Section 1A values do not include observations made when
the recirculation pump was out of service.
** Not applicable.
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100
Erosion and corrosive attack on the slurry piping will result in
reduced scrubber performance and availability. Clogged nozzles will
reduce liquid slurry flow rates. Holes in piping will require that
scrubber sections be taken down for repair.
The problem of corrosive and erosive attack on piping is impossible
to avoid in particulate scrubbers operating on powerplants. Resulting
problems can, however, be minimized to some extent by an ongoing inspec-
tion system. During shutdowns, nozzles should be inspected for rubber
liner pieces. Devices, such as sonic detectors, can be used to measure
pipe thicknesses at critical wear points. Nozzle plugging can be mini-
mized to some extent by replacing nozzles with flow diverter cones which
essentially have no internal parts to clog.
Presaturator Buildup
Solids accumulate in the presaturator section in the area around
presaturator spray nozzles called the wet-dry interface. In this area,
the presaturator surfaces are alternatively exposed to the hot, dusty,
gas stream and to the cool, wet, presaturator spray. A solid buildup
results, and as the size of the buildup increases, parts of the buildup
can break loose, fall into the scrubber hopper and plug the recircula-
tion pump inlet screens. In addition, as noted in the Unit 3 inspection,
the presaturator buildup can reach the point where gas flow is restric-
ted and the flow balance is altered not only within the scrubber section
but also between scrubber sections. Besides affecting screen plugging
and flow balance, presaturator buildup may form hard deposits which
require extreme methods for removal, such as using a jackhammer to break
up the solids. Damage to the underlying presaturator surface then may
result.
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101
PSCC has attempted to minimize the presaturator buildup problem
by directing the nozzle sprays so that they point 45ฐ into the scrubber
rather than being oriented at 90ฐ, i.e., vertical. This modification
has apparently helped to some degree but, based upon the Unit 3 equip-
ment inspections, there is still a need for frequent inspection and
cleaning to prevent excessive presaturator deposits from developing.
This is especially true for Units 1 and 3 where flow distribution prob-
lems are more inherent and where spare modules are not available.
Other modifications to further reduce the solids buildup problem
might include reducing the inlet particulate loading and providing a
means to constantly wet the wet/dry interface area. Decreasing the
inlet particulate loading could be achieved by improving the ESP collec-
tion efficiency. Wetting the presaturator area might be accomplished by
irrigating the bottom surface from a pipe located just upstream of the
wet/dry surface.
Mist Eliminators
The mist eliminator installations have presented continuing diffi-
culties in the operation of the Universal Oil Products scrubbers.
Problems have arisen in two areas: high pressure drop, and high mist
entrainment. The high pressure drop problem was thought to be caused by
the initially installed FRP mist eliminators which may have tended to
"flutter" when the scrubbers were in service. This problem has re-
portedly been solved by the substitution of 316 SS mist eliminators.
The problem of high mist entrainment is indicated by the outlet
particulate analyses conducted by MRI and by the reheater heat balances
conducted by PSCC. Obviously, high carryover not only affects reheater
performance but also accounts for decreased scrubber availability due
to reheater pluggage from solids carried over with the entrained mist.
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102
Furthermore, mist carryover can cause a high percentage of submicron
participate to be emitted which may not contribute much to the total
weight of particulate emissions, but can have a significant adverse
impact on the opacity of those emissions.
The problems of high mist carryover can originate from a number
of sources. Based upon equipment inspections and discussions held with
the Company, mist eliminator blade alignment and mist eliminator plug-
ging are not significant trouble areas. However, sources which nay
directly or indirectly contribute to high mist carryover are: the heavy
mist eliminator inlet loadings, gas flow, liquid entrainment maldistri-
bution, inadequate mist eliminator removal efficiency, and re-entrainment.
Unfortunately, very limited droplet loading, mist particle size, and
flow distribution measurements have been made for the mist eliminator;
however, it must be pointed out that well-developed droplet measuring
methods are not presently available. It is apparent, nonetheless, that
there are significant gas and liquid flow distribution imbalances to the
mist eliminators. This is indicated from velocity measurements, evi-
dence of gas flow channeling within the scrubber, and plugged water
nozzles. It is not certain how these imbalances are propagated through
the mist eliminator, although the normal &P across the mist eliminator
(typically 2 to 5 cm W.C.) is probably not sufficient to even out sig-
nificant flow imbalances.
The Company approach to reducing mist carryover is to improve
the removal efficiency of the mist eliminators by using a more effi-
cient design. They have installed new mist eliminator designs in
section 3A (Heil Model EB4) and section 3C (Munters Model T271). The
Universal Oil Products manufactured chevron unit is a 3-pass mist
eliminator with a 90ฐ angle between blades and an offset distance
between blades of approximately 4 cm. The Munters Model T271 is a
chevron type mist eliminator but is composed of trapeze-shaped sepa-
rating walls with integral liquid drainage channels. The offset distance
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103
between blades is about 5 cm. The Heil Model EB4 is a 4-pass chevron
with 4 cm offset between blades. The mist eliminator uses hooks to
collect moisture and minimize pressure loss due to turbulence.
Table 22 presents a comparison of the design features of the exist-
ing mist eliminators in service. Although the new mist eliminator
designs may provide some advantages, it is difficult to reach conclusions
from the data presented in the Table. However, there is strong evidence
to indicate that more extreme mist eliminator design changes may be
required to provide acceptable mist reduction.11 Potential changes
include using a vertical mist eliminator or a two-stage mist eliminator.
The major difficulties which result from the Company mist elimi-
natcr program are twofold. First, to properly improve mist eliminator
design, the conditions under which the mist eliminator is operating
must be fully understood. Questions which must be answered include:
How significant is the gas flow distribution problem? What mist
carryover loadings, drop sizes, and imbalances will the mist eliminator
see? These are difficult questions to answer, but without some
insight, possible solutions to the mist eliminator problems become
very difficult, lengthy trial-and-error endeavors. Second, in evalu-
ating new mist eliminator designs, it is important to minimize the
effect of other variables. If the effect of these variables is not
minimized, then a design may be discarded because it was exposed to more
severe operating conditions, even though it may be superior to the other
designs. This could very easily happen at the Cherokee Unit 3 scrubber,
where a number of potential problems affecting mist carryover are known
and have been observed to occur.
It is not very likely that modifications other than well-developed
design modifications will markedly improve the mist carryover problem.
Modifying operating variables such as gas velocity and L/G to improve
mist carryover are not plausible. For example, gas velocity and L/G
-------
Table 22
COMPARISON OF VARIOUS MIST ELIMINATORS
INSTALLED IN TCA SCRUBBERS
CHEROKEE STATION
PUBLIC SERVICE COMPANY OF COLORADO
o
-P.
Mist
Eliminator V
Type
UOP 3-pass stain-
less steel chevron
Munters Euroform
Model 271 *
Heil Heilex
Model EB-4f
Gas
elocity
Range
mps
2-4
2-7
2-7
Pressure Minimum Separation Maximum Velocity
Drop Drop Size Efficiency for Liquid Load for
Ranqe Collected Min. Drop Size 0 Reentrain.
cm W.C. um % kg/hr-nT mps
2-3 10 85-95 5% of gas 4
flow by weight
2-7 Unknown Unknown 24.5 7
0.1-0.5 10-20 85+ Unknown Unknown
Reentrain.
Drop
Size
urn
100-500
Unknown
Unknown
t Data from product literabure.
-------
105
changes are restricted by the fact that the scrubber must treat all the
boiler offgass and must operate at a L/G ratio dictated by particulate
removal requirements. Improvements due to revamped maintenance practices
are also unlikely. Obviously, the scrubber can be more frequently in-
spected and overhauled, but it is questionable whether this is a practical
procedure for a bas-loaded plant.
Given all these aspects of the mist eliminator problem, it is not
expected that the improvements initiated by the Company will have a
major impact on upgrading scrubber reliability. Rather, more extreme
measures such as reducing upstream gas flow and liquid imbalances,
adding an additional mist eliminator stage, or changing the position of
the mist eliminator to a horizontal rather than vertical duct may be
necessary.
Scrubber Booster Fan
Recurring problems with booster fans have been noted in upset
reports throughout most periods of scrubber operation. These upsets
vary from fan bearing, alignment, and vibration problems caused by
build-up of ash on fan blades to more serious problems of erosive wear
of the fan blades caused by the highly abrasive nature of the ash. This
latter problem is especially critical for Unit 4 since it utilizes air
foil type fans (dictated by volumetric flow rate-pressure drop require-
ments) as opposed to the radial tip fans used on Units 1 and 3. Air
foil fans are extremely sensitive to erosion and fan performance rapidly
deteriorates under highly erosive conditions. Obviously, when a fan is
taken out of service, part of the gas flow must be bypassed to the stack
or to a spare module, if available.
These fan-related problems are difficult to avoid in light of the
relatively high dust concentrations involved, even with properly operated
-------
106
fan soot blowers. The most readily apparent solution is then to upgrade
the performance of the ESP's, and thereby reduce the concentration of
fly ash which the fans must handle. The problem of the fan blade wear
on Unit 4 caused by the highly abrasive ash might also be reduced by
using harder alloys.
Weather-Related Problems
The freezing of lines during cold weather continues to be a poten-
tial problem for the Unit 1 and 3 scrubbers but the magnitude of this
problem could not be evaluated from upset data or from observations made
during the July-August 1977 observation period. In general, freezing
can cause leaks in piping, damage valves and cause portions of the
slurry and water streams to become inoperative. The particulate removal
performance of the scrubber may then be reduced or sections of th&
scrubber may need to be taken out of service for repair. The Unit 4
scrubber is enclosed and does not have significant freeze problems. On
Units 1 and 3, the Company, reportedly, attempts to drain water and
slurry lines when the scrubber is taken out of service for long periods.
Difficulties are said to typically result during shutdowns when there is
not enough time for proper drainage.
Outlet Ductwork
The ductwork at the outlet of the scrubbers is unlined carbon steel
and is highly vulnerable to corrosive attack. When the scrubber re-
heaters are not in service or are not operating properly, the ductwork
is exposed to gas which is at or below its dewpoint with respect to
sulfurous and sulfuric acid. The acid collects on the ductwork surfaces
and the metal is attacked. The result is corrosion and rusting of the
carbon steel with accompanying loss of structural integrity. Holes
form in the ductwork, allowing gas to escape; acid condensation then
can occur on nearby structural supports, insulation, etc.
-------
107
Inspection of the Unit 3 scrubber indicated that extensive corro-
sion has already occurred in the outlet ductwork. Likewise, although
outlet ductwork on Unit 1 and 4 scrubbers wasn't inspected, it is
expected that with similar reheater problems, these units will also have
severely corroded ducting. At this advanced stage, covering the carbon
steel with a protective coating may not be feasible. Therefore, re-
maining options are to immediately repair ductwork failures as they
occur and reduce the amount of time that the scrubber is operated when
the reheater is defective. Complete replacement of outlet ductwork
sections is not advisable until the reheat problem is solved.
-------
VII. OPACITY
EVALUATION OF INSTRUMENTATION
An evaluation of the instrumentation used for measuring smoke
density was conducted on July 7 and 20, 1977.
Units No. 1 and 2 exhaust to opposite sides of a single 91 m
(300 ft) stack, with a 4.9 m (16 ft) exit diameter. The opacity of
Unit No. 1 is measured by a Bailey Dust/density transmitter (bolometer)
installed in a 2.1 m (7 ft) wide duct a short distance from the stack.
The light source and light detector are on opposite sides of the duct
and are joined by a pipe to maintain alignment of the system. Purge
air is supplied to both sides of the system to reduce dust accumulation
on the lenses. The standard installation, which is indicated to be in
place, utilizes a 10 cm (4 in) diameter pipe with a 1.5 m (5 ft) x
3.25 cm (3.25 in) slot across which opacity is measured. The dust
path is normal to the plane of the slot. The opacity is registered on
a 24-hr circular chart recorder. A clock accumulates the intervals
when the opacity exceeds 20%.
Every day the lenses of the transmissometer are cleaned and the
recorder charts replaced. All opacity charts are kept at the plant
for a one-year period. Unit No. 1 has reheat problems which have
reduced the temperature in the duct to about 52ฐC (125ฐF). This low
temperature reportedly permits ash buildup on the Bailey pipe and
reduces the cross-sectional area along the light path. A brush is
used to ream the pipe while the unit is in service. During outages
the ash buildup is removed by chiseling.
-------
110
The meter on Unit No. 2 is the same as on Unit No. 1, but is
installed across a 2.6 m (8.5 ft) duct. Daily maintenance is the same
for each Bailey meter.
Unit No. 3 exhausts to a 91 m (300 ft) tall stack with a 5.9 m
(19.5 ft) exit diameter. A Bailey meter, as described above, is in-
stalled across a 2.3 m (7.5 ft) duct leading to the stack. A reheat
problem exists with Unit No. 3. This has allowed ash buildup similar to
that occurring on the piping of the Bailey meter on Unit No. 1.
Unit No. 4 discharges to a 122 m (400 ft) stack with a 6.7 m
(22 ft) stack exit diameter. Two Bailey meters are installed on the
discharge side of the induced draft (ID) fan. A scrubber downstream of
these meters negates use for emission measurements. However, the
meters are used for adjusting performance of the unit. A Lear-Siegler
RM-4 transmissometer is installed in the duct between the scrubber and
the stack. In contrast to the Bailey meters, the RM-4 contains the
light source and detector in a single housing on one side of the duct.
A pipe is not used to maintain the alignment across the duct. Unlike
the older Bailey meters, the RM-4 electronically converts opacity
measurements in the duct to read stack exit opacity. The conversion
factor is set at the factory prior to installation.
A Leeds and Northrup Speedomax strip chart recorder registers the
output of the transmissometer. Charts are replaced when the end of
the roll is reached. Plant personnel have found that purge air is
effective enough to only require lens cleaning every six months. The
filter on the air cleaner must be cleaned every three months.
Operation and maintenance procedures for all meters were found
to be acceptable. The location of opacity meters on Units No. 1-3
-------
Ill
was also adequate. However, the Lear-Siegler transmissometer is located
between two horizontal bends which may create a non-uniform particle
distribution.
On July 20, 1977, the Bailey meters on Units No. 1, 2 and 3
were calibrated using a procedure developed at NEIC and standard
screens of known opacity (20, 40, 60 and 80%) supplied by the Bailey
Meter Company. The Lear-Siegler monitor was not calibrated since
that company only supplies an internal standard and NEIC is only now
developing a field calibration system for that unit. The procedure
permits a check of the linearity and span of the meter while the unit
is in operation. A sample calculation is shown in Appendix E.
The test procedure requires that calibrated filters or screens be
inserted in the light path to simulate opacity measurable by the trans-
missometer. The opacity (0) scale is not a linear function but is
related to optical density (OD) by the relationship.
OD = -log1(J (1-0)
The optical density is linear and, therefore, is additive while opacity
is not. If the duct where the opacity monitor is installed is measuring
a background opacity because a unit is in operation, the optical density
of screens being inserted is additive to that in the duct. Thus, if a
monitor is reading 15% opacity (OD = 0.071) and a 20% opacity (OD =
0.097) screen is inserted, the resulting opacity should read 32% (OD =
0.071 + 0.097 = 0.168) rather than 35% (20% + 15% = 35%).
If the relationship between the meter output and the screen opacity
is linear with a 45ฐ slope when plotted in optical density units, then
the relationship between meter output and stack opacity is linear
[Figure 13]. If, in addition, the meter reads 100% when the light
-------
112
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Optical Density - Screens
Figure 13. Calibration Curve of Instrument in Calibration
Cherokee Station - Public Service Company of Colorado
-------
113
beam is either completely obscured or extinguished, then the meter can
be assumed to be in calibration since a line through the 100% opacity
point at 45ฐ slope would also intersect the origin.
When an optical density plot of the meter output vs screen opacity
is linear but not a.t a 45ฐ slope, then the relationship between re-
corded output and stack opacity is not linear and the meter is out of
calibration. In this case the scale is distorted, being elongated if
the slope is greater than 45ฐ and shortened when less than 45ฐ. If
elongated, the meter will read higher for a given stack opacity, if
shortened it will read less. In these cases the meter will still
appear to pass through 100% opacity when the light beam is extinguished
and, since the zero opacity is not usually measurable during process
operations, the transmissometer is thought to be in calibration.
The major problem in calibrating a transmissometer appears to
arise from units calibrating near 100% opacity. Figure 14 shows the
relationship between opacity, transmittance and optical density. The
difference between 0% and 90% opacity is 1 OD unit. The difference
between 90% and 99%, or 99% and 99.9% is also 1 OD unit. Thus, cali-
bration procedures causing large changes in optical density result in
minor differences in opacity near 100%, but significant variations
in the usual range of opacity readings.
While the above calibration procedure is adequate for checking
span linearity, it will not determine whether the background opacity
reading is a result of smoke in the stack, or is attributable to dust in
front of or behind the lenses.
When the smoke density meter on Unit No. 1 was calibrated [Figure
15], the unit was burning 100% natural gas. The recorder was reading
-1%, and with the light source extinguished, 99%. The data were shifted
-------
114
100.0
0.1
0 1.0 2.
Optical Density
Figure 14. Relationship Between Optical Density,
Transmittance and Opacity
Cherokee Station
Public Serice Company of Colorado
-------
115
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0.2
O.I
Optical Density - Screens
Figure 15 . Calibration of Bailey Smoke Density Meter on Unit No 1
Cherokee Station - Public Service Company of Colorado
-------
116
1% upscale before being calculated to account for this offset. Figure
14 indicates that while the linearity is acceptable, the instrument span
appears shortened. The shortened span causes reduced output for a given
opacity, even though the 0% and 100% points are acceptable. Some of the
data points of Figure 14 are indicated as vertical lines where recorder
fluctuations (due to opacity variations in the duct) occurred during the
calibration procedure.
Unit No. 2 was burning a mixture of 25% natural gas and 75% coal
when the smoke density meter was calibrated [Figure 16]. This resulted
in a higher background opacity in the duct (6%) as compared to Unit
No. 1. When the light source was extinguished, this meter also read
99%. The linearity appears acceptable, however, the span of this
unit also is shortened although not to the extent of the meter on Unit
No. 1.
If the slope of the line fitting the data is considered an indi-
cation of the span, a 45ฐ line (an instrument in proper calibration)
would have a value of unity. The opacity monitor on Unit 1 has a
slope of 0.70, indicating a span that is 70% of the acceptable value.
In a similar fashion,.the monitor on Unit No. 2 had a span of 91% of the
desired value.
Unit No. 3 was only burning coal when the opacity monitor was
calibrated, thus it was registering a slightly higher opacity (9%)
than the other two meters. With the light source extinguished, this
meter also read 99%. Again, the linearity appeared acceptable but the
span was foreshortened to 86% of the expected value [Figure 17].
In all cases the compression of the span will result in the recorded
value being less than the measured value in the duct.
-------
o
o
ra
ex
O
i
-------
meter in proper^
calibration
0
Optical Density - Screens
Figure^. Calibration of Bailey S,^okp nensity Meter on Unit No. 3.
Cherokee Station - Public Service Co;-Dany of Colorado
-------
119
In addition to the lower opacity reading indicated above, it should
be noted that the three meters are only reading smoke density across a
1.5 m (5 ft) path length (the length of the slot in the pipe). Below is
a comparison of this length with duct and stack exit diameter for each
meter.
Slot Length Duct Hidth Stack Diameter
Meter No. m
1 1.5
2 1.5
3 1.5
ft
5
5
5
m
2.1
2.6
2.3
ft
7
8.5
7.5
m
4.9
4.9
4.9
ft
16.0
16.0
19.5
Since the opacity is a function (logarithmic) of the path length,
the meters are only measuring a portion of the opacity when the slot
does not extend across the duct. Also, since the ducts are all narrower
than the stack exit diameters, the opacity measured at the stack exit
would be greater than measured across the duct (all else being equal).
The following relationship relates opacities to varying path lengths:
Iog10 (1-0-,) log1Q (1-02)
where 0, and 0ซ are opacities measured across distances d, and d~- For
example, if the meter on Unit No. 3 was reading 10% opacity (across the
1.5 m slot), a meter across the duct (2.3 m) would be expected to read
15%, while 34% opacity would be expected at the stack exit (5.9).
These differences are significant and also indicate a case where the
meter would be reading below 20%, therefore not requiring a report to
State and Federal agencies, while the opacity at the stack would be
above the value that requires notification. As indicated earlier, the
-------
120
Lear-Siegler transmissometer corrects for this difference and reports
exit opacity.
In the case of Units No. 1 and 2 which exhaust to the same stack,
the observed stack opacity would be a function of the opacities in each
duct, but in all cases would be greater than the opacity from a single
source. The relationship is given by the equation:
log (1-Oj) + log (1-02) = log (1-0S)
d~T^ d;
where 0,, Op and 0 are the opacities recorded on Units 1 and 2, and
the opacity of the stack and d,, dซ and d are the meter path lengths
1.5 m and the stack exit diameter 4.9 m, respectively.
Using the above equation, it is possible to determine the re-
lationship between the two opacity meters that will produce a 20%
opacity at the stack as follows:
Opacity
Either Unit
0
2
4
6
8
10
12
Opacity
Other Unit
13
11
9
7
5
3
1
Exit Stack
Opacity
20
20
20
20
20
20
20
The table shows that when either meter is reporting over 13% opacity,
the stack exit opacity will be >_ 20% and that even with opacities as
low as 7% on each meter this condition can occur.
-------
121
Even with proper operation and maintenance, the three meters
examined were out of calibration in that the span was foreshortened on
all three. However, when this problem is corrected, the meters will
still not be making the measurement that is desired; i.e., the opacity
of the plume at the stack exit. Thus, when the Company reports the in-
cidence of opacity greater than 20%, it will be occuring across the
1.5 m (5 ft) slot and not at the stack exit. On the other hand,- as the
examples showed, 20% opacity may occur at the stack exit and go un-
reported because the meter is reading less across the slotted pipe.
The deficiencies in the plant monitoring system can be corrected
by the following:
1. The three Bailey units should be calibrated using the 40%
opacity plate or a filter in that range. This should be done by adding
the optical density of thn duct opacity to that of the plate or filter
to determine a total optical density. When this total is converted to
opacity, the value should be set on the meter. Because the meters are
presently out of calibration, this may initially require several
iterations since the duct opacity will be in error.
2. The reporting requirements for Units 1 and 2 should be modified
to account for the relationship shown above. This may be done either
by installation of electronic circuitry designed to output the relation-
ships between the two instruments to produce a recording of combined
stack exit opacity or by use of the above table computing this relation-
ship.
3. The reporting requirements for Unit 3 should be modified to
account for the relationship between opacity across the 1.5 m (5 ft)
slot length and the 5.9 m (19.5 ft) stack exit diameter. From the
relationship between opacity and path length, 6% opacity at the bolo-
meter will correspond to 20% at the stack exit (all else being equal).
-------
122
VISIBLE EMISSION OBSERVATIONS
During the study period, visible emission observations (VEO) were
randomly made on the three boiler stacks at Cherokee Station. The
VEO's were made by eleven different NEIC observers using EPA Method 9.
A summary of the observations is given in Table 23. Appendix B contains
a listing of the VEO's for the individual stacks at Cherokee. During
the study period, 92 VEO's were made and the average opacity exceeded
20% during 51 of those observations [Table 23]. Because the opacity
regulations in the State Implementation Plan (SIP) has no time limita-
tion, the individual readings were also summarized for the set of 51
observations. Of 1,374 individual readings, 949 exceeded 20% but
were less than 40% opacity.
During the July and August VEO's, an NEIC observer monitored the
j.
plant operation and recorded unit load, fuel type, opacity meter
readings and control equipment data. This data was recorded before
and after each VEO [Appendix A]. Only the process data was recorded
during the October VEO's and were normally recorded after the observa-
tions were made. It was not possible to correlate the VEO readings
with the Bailey opacity meter readings. The readings did confirm the
calibration tests results that indicated the stack opacities would be
greater than the Bailey Meter readings, due to path length differences.
The average stack opacities read by the NEIC observers were greater than
Bailey meter readings. Because the Bailey meters were found to be out
of calibration, the VEO's were not compared to calculated stack opaci-
ties. It is recommended that once the deficiencies in the opacity
monitoring system are corrected, that actual VEO's be compared to the
calculated stack opacities to ensure that the meters are accurately
recording exit stack opacities.
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123
Table 23
SUMMARY OF VISIBLE EMISSION OBSERVATIONS
CHEROKEE STATION
PUBLIC SERVICE COMPANY OF COLORADO
Stack
No. of 6 min No. of Times
Observations Average Opacity
>20%
No
Total
. of Readings
>20%
<40%
>40%
July 27-August 28, 1977
Unit 1 & 2
Unit 3
Unit 4
Unit 1 & 2
Unit 3
Unit 4
TOTALS
34
10
27
October
No. of 9 min
Observations
7
7
7
92
23a
8"
7
4-18, 1977
5fc
5d
3e
51
552
192
170
184
168
108
1,374
417
113
110
72
74
63
949
4
57
0
12
90
23
186
a The recirculation pump for section A of the scrubber was out of service
during 13 of these periods.
b Unit 3 scrubber was off-line during entire period. Fuel was 50% coal
and 50% gas. Unit 3 down for scheduled outage on 8/20/77.
c Unit 1 reheater plugged. Scrubber being bypassed three of these periods.
d Recirculation pump out of service one time and booster fan out with
50% bypass during other four observations.
e Unit startup during one observation.
-------
VIII. PARTICULATE CONTROL SYSTEM RELIABILITY IMPROVEMENT
Before any discussion of alternatives to improve system reliability
is presented, there are a number of related topics that should be re-
viewed. Some consideration must be given to the ultimate reliability
goal to be attained. Thought must be given to how various options for
improving reliability are to be evaluated. It must also be recognized
that economics and redundancy will have a large impact on reliability
considerations.
A determination of required system reliability is of primary im-
portance. There are a number of ways of expressing system reliability
but normally it is done on the basis of percent boiler on-line time.
An "acceptable" percent reliability will vary and depend on, among
other things, the specific application, and revelant SIP regulations
as interpreted by the administering agencies. Ninety percent relia-
bility is considered to be achievable for powerplant flue gas desul-
furization processes and is also acknowledged to be within the limits
of particulate removal technology by most particulate control equipment
manufacturers. The State of Indiana requires 95% reliability for
meeting their particulate regulations.
A method is also needed to gauge how various modifications will
affect reliability. If the necessary reliability component data is
available, it is possible that reliability analysis techniques pioneered
in the nuclear industry could be applied to particulate control systems.
For example, when reasonable estimates of mean time to failure and mean
repair times of critical equipment can be made, then a fault tree analy-
sis can be conducted and quantitative comparisons can be obtained.
Otherwise, reliability analysis must be left to qualitative engineering
judgments which are often subject to extensive debate and disagreement.
-------
126
Economics will be an important part of comparing control plan al-
ternatives. Any system can be upgraded to provide 99.9%+ reliability.
The cost of that system, however, may be prohibitive. Although eco-
nomics were not evaluated in this study, such effects must be considered
in any further analyses.
Redundancy will be a key factor in achieving consistent operation
of any particulate control system. Equipment used in near continuous
service and exposed to dusty environments, variable temperatures and
corrosive conditions will eventually break down. Therefore, to achieve
reliable operation under such circumstances, it is necessary to provide
spares for critical equipment components. The problem is in determining
which are the critical components. Some of the areas of improvement are
discussed below.
SCRUBBER IMPROVEMENTS
There are numerous areas for improvement suggested from the scrub-
ber evaluation. In this section, only those changes which are con-
sidered to have a significant impact on scrubber reliability are pre-
sented. These include: adding spare scrubber capacity, replacing the
direct reheat systems with indirect reheat, adding spare recirculating
pumps, providing for more frequent inspection and cleaning of those
scrubbers that don't have spares, improving the mist eliminator design,
improving the mobile packing design, and providing an enclosure for all
scrubber sections.
The addition of spare scrubber modules would have a very significant
effect on reliability. Provision for spare modules would allow for a
scheduled maintenance program in which modules would be routinely taken
offline for cleaning and repair. A spare module would also allow for
switching modules on- and offline when emergency repairs were required.
-------
127
On those units with direct reheaters, improvement in scrubber
availability would be realized if the direct reheaters were replaced
with indirect reheaters. The in-line tubes are subject to plugging and
corrosion which is highly dependent on upstream scrubber and mist elimi-
nator conditions. The ability of indirect reheaters to stay in service
is much less dependent on such conditions. As an added advantage, in-
direct reheat air fans can be used to provide fresh air to scrubber
sections during maintenance, reducing the need for tight isolation
damper shut offs.
Adding spare recirculation pumps is considered very important in
improving operation of single-pump scrubber sections. When a recircula-
ting pump is out of service in a single-pump section, the section must
be taken off line or operated under very reduced capability. Adding
spare recirculation pumps to a scrubbing section which has three operating
pumps is less critical.
Increased frequency of inspection and repair must be considered as
a potential alternative for improving reliability on Units 1 and 3.
PSCC's current maintenance practices and thoroughness in performing
maintenance does not appear to be improper. The problem occurs when
scrubber instrumentation does not always indicate when scrubber internal
problems are occurring. Detection of such problems then requires frequent
visual inspections. Unfortunately, the practicality of frequent visual
inspections on a base-loaded plant is questionable. Furthermore, the
required frequency at which inspections must be made is affected by the
quality of the coal fired, the operation of the plant, the operation of
the ESP's, etc. An optimal inspection frequency will be different under
different conditions.
PSCC is currently attempting to improve the operation of the
scrubber system by improving the mist eliminator design. The success of
this effort will depend on how scrubber operations affect new design
-------
128
considerations, and how the mist eliminator tests are being conducted.
Any program of this type must be considered a research effort and will
require time for adequate tests to be run and evaluated. It is probable
that the Company will have to resort to major mist eliminator modifi-
cations, such as installing two horizontal mist eliminator stages or a
single vertical mist eliminator stage, to markedly reduce mist entrain-
ment.
The improvement of the scrubber operation is very significantly
affected by the type of packing used in the scrubbers, and PSCC has
expended considerable effort in this direction. They have not tested
stationary packings; however, and in view of success of stationary
packings observed in other related applications, this appears to be an
area which should be thoroughly investigated. As in the case of im-
proving mist eliminator design, a research and development effort is
required and additional time will be needed for proper evaluation.
Enclosing the scrubbers on Units 1 and 3 would reduce down time due
to freezing lines. This has proven effective on the Unit 4 scrubbers.
ESP IMPROVEMENTS
The evaluation of the precipitators was hampered by not knowning
the flow of gas conditioning agent to the boiler off-gases. The first
area of improvement should be to add flow monitoring devices to monitor
the SO, flow to each of the units (including Unit 3), then an evaluation
program must be undertaken to determine the effectiveness of the gas
conditioning on ESP efficiency. Once this is done, the operation of the
ESP may be inproved to the point of meeting design efficiencies. Major
modifications would need to be undertaken to significantly improve the
collection efficiency of the ESP's and thus reduce the particulate
loadings to the scrubbers and to the stack in the case of Unit 2. These
-------
129
would include adding more electrical sections, increasing collection
plate area, and upgrading the automatic control systems. Adding more
electrical sections would increase the power input to the ESP's and
provide for higher corona power and current densities. This would also
provide for a more efficient and reliable precipitator since a smaller
portion of the precipitator would have to be taken out of service when
broken wires are changed. Enlarging the precipitators by increasing the
plate area would probably be the most expensive way of increasing the
efficiencies of the precipitators, since this would essentially be the
same as adding a new precipitator to the existing system. The existing
automatic controls are of the saturable core reactor type and are
typically slow in responding to voltage changes. This is especially
critical if excessive sparking occurs and the controls do not respond
fast enough to prevent corona wires from burning out. This was not ob-
served during the study but may be a problem if higher power inputs are
wanted.
The previously discussed improvements were based on evaluations
made on the existing participate control equipment. Other alternatives
not evaluated in this report, include replacing the existing equipment
with high efficiency (+99%) precipitators or replacing the scrubbers
with baghouses. These options should also be considered when evaluating
a program for improving reliability.
-------
130
REFERENCES
1. August 5, 1977. Letter: from Robert L. Pearson - Public Service
Company of Colorado, Denver to Irwin L. Dickstein - Environmental
Protection Agency, Region VIII, Denver.
2. August 8, 1977. Letter: from George P. Green - Public Service
Company of Colorado, Denver to Irwin L. Dickstein - Environmental
Protection Agency, Region VIII, Denver.
3. White, H. J. 1977. Electrostatic Precipitation of Fly Ash.
Journal of the Air Pollution Control Association 27:3, p 206-217.
4. Meteorology Research, Inc., Nov. 1975. Evaluation of Particulate
Scrubber on a Coal-Fired Utility Boiler. Environmental Protection
Agency: EPA 600/2-75-074, 81 p.
5. Calvert, S. et al., Oct. 1974. Eine Particle Scrubber Performance,
Environmental Protection Agency: EPA 650/2-74-093, 258 p.
6. Statnick, R. M. and Drehmel, D.C. June 1974. Fine Particle Control
Using Sulfur Oxide Scrubbers. 67th Meeting of the Air Pollution
Control Assoc., Denver, Colorado, Paper No. 74-231.
7. Uchida, S. et al. Aug. 1977. Mechanics of A Turbulent Contact
Absorber. The Second Pacific Chemical Engineering Congress, AICHE.
New York, p 1251-1267.
8. Calvert, S. et al. Aug. 1977. Liquid Entrainment From a Mobile
Bed Scrubber, Journal of the Air Pollution Control Association*
27:8, p 768-770.
9. Johnson, J. M. et al. Oct. 1976. Scrubber Experience at Mohave.
Conference on Particulate Collection Problems in Converting to Low
Sulfur Coals. Environmental Protection Agency: EPA 600/7-76-016,
p 208-224.
10. Choi, P.S., et al. Feb. 1977. Stack Gas Reheat for Viet Flue Gas
Desulfurization Systems. Electric Power Research Institute: EPRI
FP-361. Palo Alto, California 73 p.
11. Battelle Columbus Laboratories, Dec. 1976. Guidelines for the
Design of Mist Eliminators for Lime/Limes tone Scrubbing Systems.
Electric Power Research Institute, EPRI FP-327. Palo Alto, Cali-
fornia, 102 p.
-------
APPENDIX A
PROCESS DATA SHEETS
CHEROKEE STATION
PUBLIC SERVICE COMPANY OF COLORADO
July - August, 1977
-------
CHEROKEE STATION UNTT 1 DATA SHEET
A-l
Date:
"Time:"
Plant
<. Gross
yc A*
Sfeam~Fl6w"" (Ibs/hr)
ML
I^fLL
./934._
' 10*
"SteamJPressure" (psigj
">_ 3.0 j Aitj-j
z.t*
E
' ,0 '
StearrTTemperature (*F) ""_ "" _._._L_320 l_.qsi_ " ~
Pumps; Recirc. Pump Al (amps
iRecirc. "Pump" Bf" (amps
Recljrc. Pump _B2_( amps
Rec1rc.~"P'ump B3 (amps)
Reheater; Steam Flow (M Ibs) _ '
Steam Pressure (ps 1 gj. ~
Section A; Presat Water Flow (gpm) ;
Outlet Gas Temp. (ฐF) .
Bed Diff. (in. HjO) " ~~
,4
e.4
.J
_.Demister Diff. (in. H20)
RH'Diff. (in. H,0) "
G'aT'Outlet'Flow'dn: H^I
g.n
0.0
^n"7-
-ii:
Section B; Presat Water Flow (gpm)
Outlet"Gas TempT(ฐF)
Bed Diff. {1n,_HgOj__'~"~:~ |~
Demi s te r_Di f f._( i n. JK2Q1 '
_RH.Diff. (In. H20}' "
Comments
Gas Outlet Flow (in. H20)
JLO.L
6.C,
O
^
rปrfnL
i>*.^ yr-nf^
-------
A-2 CHEROKEE STATION UNH 1 DOT<\ S"EET
Date: 8/*/77
"Time: fcSD ,,-. /B(?t? ff
i Plant QAf&
! ฃ.aAS> ' 113.
Mw, Gross 111 \o<\ . -.-4L4 '*-
XS 02 % ~*2~8 ' cS.T J.f 3'^-..L.- - -/.6
"" Steam Flow (Ibs/hr) x/o* " y/} ~7.i fat. . Z0 ' *ฃ
"" Steam Temperature (ฐF) /O2.O /cS .3*,.- - - *?
Opacity, ScrutibjuMgi) rMgc
A/AT, $/>5 AflM> &C/=>y) " O O O O
ESP
Section A1-A2; AC Voltage
AC Current
DC Voltage
"DC Current
" Spark Rate
Section B1-B2; AC Voltage
" AC Current"
"DC Voltage
DC Current
_ Spark Rate
v)
ซ}
Kv)
ma)
_spm)
v)
a "
Kv)
ma)
spm)
t-Qtl0 r-~-ti* nt is* Sflly'O .ฃf3.J^t. 4a
?S 9-ltt.
Hfitlo
"no . ">s t7?_ ns
JOOtZO
Scrubber ' * .
Fans; Fan Inlet Pressure (in. H20) vtfr "O.3 -(J,if -0>3f ~ '*
Fan.A .Outlet Pressure (in. H20) " ~ *" "~
Fan B Outlet Pressure (in. H20)
._ . . Fan A.Araps .. ..... /4f /3> 4& 4
RH Diff. (in. H,0) 3.f n/
OIซ^ATCซ CO*TA.'<- c&urf/t
-------
CHEROKEE STATION UNIT 1 DATA SHEET
Date: e/a/-?? ป/<^/^^ &>**h'i
Time: - rifSkni- /O7C /^**"(
Plant
torf. Gross , 1(7 UP il~1
XS 0? 20- ' /-ft ?, 2.
e/V7?!
i^--^-
,/-?
a.i
Steam Flow (Ibs/hr) lf>* 9,^ i * 4- ป *r ^*
Steam Pressure (psig) ?4*j /a^o />faj
Steam temperature (ฐF) ' yoi^ i i^>iO ' /oiS
Oeacitv. ftvsa&s (x) : 7 7 i <*
BpOOltyi SCTUbbog (ฃ) fool 1:0*1] Cne,} : ฃon\
^Atat 1. C7r., -lew t i.c.^3 -p.
Section A1-A2; AC Voltage tv) 'E-Q ' >7y (Ss-^
AC Current1 (*) '4^-1? ir,^^ '4oti\i
/4So.
i
i
R
DC Voltage (Kv) ^1'' "**-! '^-^ ' ^
DC Current (ma) . ^/-^ p/^ ^P
bpark Rate ( spm) a-i.-jz.tc3 ai,^ dti.-to
Section B1-B2; AC Voltage (v) i ,<>- : isx- tฃ*
AC Current a) ;^rt/o -vrt/o ?^ฑ/r,
T'-H'-.
1
UI
!
' i
> i
| . . .
' i
DC voltage i Kv) ,*,..*. ^ .4- f-.-t- O.J-T
DC Current ma) ^O /ฃ7t? ' <9o /oo
I
Spark Rate spm) aoO-it ^3.
Reclrc. Pump Bl (amps 2,.V -?) ^,.5- , 7j t
Reclrc. Pump BZ (amos 20 f ap- >o - ' :>t> =
Reclrc. Pump B3 (amps, o O O L>
Reheater; Steam Flow (M Ibs) o^r &u>'r e>wh Ou\-
Steam Pressure (psiq)
Section A; Presat Water Flow (gpm) 4-7 ฃri ^.7
Demister Diff. (In. H?0) 3^ '2S- 2i<
Outlet Gas Temp. ("FJ ฑ^- } .^ ,%ฃ. 1 ,^t
... Bed Diff. .(in^HjOL^. c* ^~ , ~cT
I Demister Diff C\n H501 / * - ? ~ ซ. -j *~1 TT-*
RH Diff (in H?0) 3-^ << 'ป ? \-
Gas Outlet Flow (In. H20) o ^ 0 ^ " Q ~| o
^ *
3
=?>
'
1 :
Comments
-------
A-4
CHEROKEE STATION UNIT 1 DATA SHEET
fez
Date:
iTIme:"
Plant
m
. Gross
T?.9"
team Flow (Ibs/hr) ^/fi.
Steam Pressure (psig}~
&O
_Steam Temperature (ฐF) " ~"
Opacity, Bysass=&) ~__
Opacity. -Sc-reubtf r (%) Cuฃ<-
_ฃL
{
14* ^
^.$0**ฐ
Section B1-B2; AC Voltage
A'C Current '
DC Voltage
0
J3Q-
_DC^ Current (ma)
jSpark" Rate _(spmjTI
6>O
50
Scrubber
F_ans; Fan.Inlet Pressure (in. HgO) r^?^a
Fan_A_Outlet. Pressure (in. HoO) _^/(?. '"
-0.3S
, 6
-0.
_Fan B Outlet Pressure.(in. HoO) _<
_Fan A_Amps
_Fan. B.Amps
Stack Damp A. JPos! (X_0pnฃ
/So
/4-0
OZ
u..
XO
jiฃL
S+0
'30
1 xj
-O-
_Pumps; Reel re. Pump Al (amps) ^3
_Recirc. Pump Bl (amps) ~
(amps)
_Recirc._ Pump B2
_Ricirc._Pump B3 (amps)
._L^ ?_
23...
7 J
Reheater; Steam Flow (M Ibs) _ _
St_eam_Pressure. .(psig)" ~
OUT
Je_ctipn A; Presat Water Flow (gpm)
_ Outlet Gas Temp. (ฐF)
" Bed Diff. (in. HzO) " '
Demister Diff. (in. H20)
RH Diff.~(in. H,0) ^.^
4-.0
*lLฑ-
2*jr
3.T
i_.
~Gas"^utlet"ซ5W (in." tf2OT
3-0
*ฃ-
J.S
ฃ.0
3/5"
{ Section B; Presat Water Flow (gpm) 23.5_]_
."Outlet"Gas TempV"(ฐF) " ~ ""' "')te>O
, Bed Diff. (in. ป2Q^~~L11'.'- -Ii*~
l Demister Diff._(in._H2b) '"/ ฑ~.^ '
RH.Diff. (in. H20)" ^'
Gas Outlet ซซw (in. H,0) /, T^
-.-.- .. pg. 2 Q-_*._ .
Comments tA/7? - tJA , i j
f.Q- .
-------
CHEROKEE STATION UNIT 1 DATA S"EET
r-
Date:
Time:
Plant
_Mw, Gross
_ XS 02 _ 3
_J_Steam Flow f'br/hr) ~~_&fi
Steaiii Pressure (psig) ' _
Steam Temperature (ฐF)
Opacity, flypast (%)
-.Opacity. Scrubber (I) &jฃL
~5M
'Me-
:7iV.C
:75/UWC
ESP
. ff/l.T
Section A1-A2; AC Voltage (v) .
~ AC Current (*}
DC Voltage
^00*10
\ lOtrtaML
/ปr>9aCM<
"DC Current
Spark Rate
Kv) J4ซ
ma)
jp"i)_m
4#][ฑ
Section B1-B2; AC Voltage.
AC" Current
DC._Voltage
DC Current
1-
aV
Kv)..
Spajk^Rate .(sprn)_
Scrubber
Fans;. Fan.Inlet Pressure (in. HgO) -
FajL-A.Outlet Pressure (in. H?0)
JLL
Fan B Outlet Pressure (in. HoO) _.,
_F.an A_Amps
Fan B.Amps
I4-.0
/b.5-
Stack Damp A. Pos. (X_0pji)~
/so
0
/so
J2-
_Pumps; Recirc. Pump Al (amps)
Recirc. Pump Bl (amps)
^23_
_Recirc. Pump B2 (amps)"^
_?IciVc7 Pump B3 (ampsj'J "
JS
Reheater;^Steam Flow (M.l.bs) _
Steam_Pressurei .(psig)'_'"_ __
&T-
i??yฐn_A;. Presat Water Flow (gpm)
Outlet Gas Temp. (8F) //<"
'""Bed Diff. (in. HjO) " . '4, V
Demister Diff. (in. H20) 4_,4-
RH Diff. (in. H20) ^-g
JGasJOut!et F4w (in.'.'H20) ?, ฃ
r ~ j
__^^LCL.L
1 /SO
us
3,
Section B; Presat Water Flow (gpm)
jDutlet Gas Temp."(ฐF) ~ " ""/A>"
Bed Diff. (in. HoOL "" fo
Demister Diff. (in. H20) ' A^'t l.o
_RH Diff. (in. H20)" " "
J>3
,*.*
IAQ
ฃT
./> }!
Gas Outlet Flow (in.
.-L.O .
L&JL
Comments
-------
A-6
CHEROKEE STATION UNIT 1 DAI A S"EET
Date:
LTime: 7_I
Plant
JVป_!5rpss
yp A.
'Steam Flow (Ibs/hr)
"Steam Pressure {psig)~~ J
'Steam Temperature (ฐF)
"Opacity,
'Opoeityr
ESP
Section A1-A2; AC Voltaqe (v)
AC Current (a) _ ;
DC Voltage (Kv) Jftt..
"DC Current (ma)
"Spark Rate
ent vino;
ate_(spm)
Section B1-B2; AC _VoH_a_ge_.(y
~KC "Current (a
DC_Voltage (Kv)..".
pC_Current (ma) ~7orIQ
Spark Rate jspm)
Scrubber
F_ans;. Fan._Inlet Pressure (in. h^O)
I Fan_A_ Outlet Pressure (in. H20)
! Fan B Outlet Pressure_(in. H20)
I Fan A.Amps
-ฃ>,3
-0. 6 ' - '
' - ^ 3
It,
_/ฅ^A_
_Fan B Amps ...
Stack Damp A^_ Pos. (j>_0pn) _"
2ฃ0_
o
O
_Pumps; Recirc. Pump Al (amps)
Recirc. Pump Bl (amps!
Rscirc._ Pump B2 (amps)
RecVrc._~_Pump B3 (ampsi
-
Reheater-. Steam Flow (M Ibs)
, dHT
_St_e_am_P_resjure_ .(ps i g)
_Sec_tion_A; Presat Water Flow (gpm)
: _ Outlet Gas Temp. (ฐF) _.
" Bed Diff. (in. H20) " " 7
i Demister_Diff. (in. H20)
RH Diff. (in. H?0)
-7. A'
f). V
IIGas. Outlet'Flow (iri'.'rtgO')
9.
M2-
-LO-
j Section B; Presat Water Flow (gpm)
' JJutlet Gas TempY"(ฐF)~" _ "'"72
\ Bed Diff. (in. H20) J'" '
>. Demister Diff._(in._Hf6)
JH Diff. (In.'HVO)
f .
Comments
Gas Outlet Flow (in. H90) /,<""
_-^_ _ '. tit.ปf--'
-*,,
, 5"
/ซ/ป
-------
CHEROKEE STATION LINTT 1 DATA S^EET
A-7
Date:
Time:
Plant
<.*>
Mw._Gros_s_
/fO
;/T*--
tip
XS Oz
"Steam Flow (Ibs/hr)
"Steam Pressure (psig)"~
'Steam Temperature (ฐF)
"Opacity,
//ฃ>
! 3.
mฃ
OUf
/4-3.O_(
l^Lh
^*4(_
TT6>'
1 I ?C
rt
ESP
Section A1-A2; AC Voltage.
" AC Current
' ' DC Voltage
" "DC Current
" Spark Rate
v)
a) ....
Kv) ;
ma) /A
spm)
. r
/frac
<9
^0*42-
/0
.&**
3&
4s,
Section B1-B2; AC Voltage.
AC "Current"
DC Voltage
DC Current
Spark" Rate
I I r !~
*ฃ*0
r_
-i^
JO?*
Kv)
ma)
spm)".
50- /o Sot/
Scrubber
fans;.Fan Inlet Pressure (in. HgO)
_ran_A_Outlet Pressure (in. H20) /4-
..Fan B Outlet Pressure-tin. H20) .
..Fan A.Amps
.Fan B Amps .
_ง*5s!L.P?n|P-.Aป .lOii-lLPR").
-0.3$ -
/S.S
n
./?
Comments
.._^./-^ i_
j it
oar
our i
(>< /"
-i_Z^i_
'-*L 3.2-
fei
J2.
e. -T
3, C>
fa,
/TO
-r.$
>
L!_2_
-------
A-8
CHEROKEE STATION UNIT 1 DATA SHEET
Bate- ?//^>/'7 fys/Tl '
Time* o '
ESP '"** *~ '
Section A1-A2; AC Voltage v). ygota) W^lo
AC Current ซj *>ฃ*e .4tf3Vg
DC Voltage (Kป) ^f^lT -Wr*~ ' J !
DC Current (ma) t4vt-4o _ Mo*Jio : .
Spark Rate (spm) ^caJyo ftCflJCo :
Section B1-B2; AC Voltaqe v) /2>^/<> i7<> '
AC Current a) (Q to !
DC voltage KVJ AUT QUJ i i :
DC Current ma) 3o ฃO
Spark Rate spm) foฃfO /ao-4co
i ' ' '
i Scrubber i ! i
1 Fans; Fan Inlet Pressure (in. H20) ~O,> -0.6
1 Fan A Outlet Pressure (inT H20) . /4- /f
Fan R OutlPt PrPซซurP (in. Hjfl) /*- (4~ . <
Fan A Amps ' 14* (S~O
Fan B Amos /^^ /ฃ~o
Stack Damp A, Pos. (2 Opn) r> r>
Pumps; Recirc. Pump Al (amps) off- o/^ ; ! ! :
Recirc. Pump 81 (amps) .?/ J/ i
Recirc. Pump B2 (amps) ' jl jt ' !
Recirc. Pump B3 (amps) A i
' 1
Section A: Presat Water Flow (apm) S$ \ $5 1 '
Outlet Gas Temp. (ฐF) //4" : //f ! '
Bed Diff. (in. H?0) , ?.^ 3,4-
Demister Diff. in. H?0) 0.3 . I,O
RH Diff. (in. H,0) T 7.7 . f.a
Gas Outlet RqT(1n. H-0)
PR
Section B; Presat Water Flow (gpm) JZ/, > ฃ/
Outlet Gas Term). (ฐF) /jr^ ff'o
Bed Diff. (in. H?0) f,6 4.& \
Demister Diff. (in. H20) 1^.3 ).1?4-
RH Diff. (in. H201 q..^ S- 0 \
; Gas Outlet-H^fin. H20) ' o ' 0, h
r: ' fi\- ........
Comments
'
I
i
.
i
i
_
i
i
1
1 !
1
!
1
-------
CHEROKEE STATION UNTT 1 DATA S"EET
A-9
Date:
Time:
Plant
JJSP.cS.
_J!w. .Gross _
XS Oz
~Steam Flow (Ibs/hr) y;-~.
"Steam Pressure (psig) "
Steam Temperature (ฐF) " ~
""Opacity, Bypaw-f*}
~0pa&ity. Scrubber (ซ) PQ,.|
"ซ?
,4ar
9 jn
<4*ft '
t?t>"
/44i2_LJi?o_:
M
10
ao
I iซ
'?
ฃฃ i
*<
ง2
( ' Coo
ESP
Section_Al-A2i..AC Voltage (v)._
" "AC Current (a)
J_ DC Voltage (Kv) |
"DC Current (ma)
Spark Rate (spjn)
Section Bl-32; AC Voltage,
' " A'C'Current"
DC Voltage
DC Current
Spark Rate
3ฃ SP-
>2c.'iC. ?7Q-Z
y) *
a) ;-ฃi,
IfcO
Ovr.
'20
feO
43Q
Scrubber , =
fans;.Fan Inlet Pressure (in. H^O). -ป3 -.4- ..4 ~.i?
Fan_A.Outlet Pressure (in.
-.7
It
_Fan B Outlet Pressure .(in. HoO)
.Fan A_Amps
..Fan B Amps
_Stad^Janp_A, Pps. (Z_QP.ni^ I
13.0
O
JiJL.
_Punips; Recirc. Pump Al (amps)
"__Recirc. Pump B1 (amps)
Recirc. Pump B2 (amps)
'Re'cfrc.' Pump B3 (amps)"
Reheater; Steam Flow (M Ibs) _ j
_Steam P.ressure .(psig)
Section A; Preset Water Flow (gpm)
_'__ " Outlet Gas Temp. (ฐF)
Bed Diff. (in. HgO)
Demister Diff. (in. H20)
3.0
_
' >H Diff. "(in. H~0)
""GaVOutlet Flow (in.'fl^O)'
p.?
4.B
8.5-
' i. f i
b -r
a o
o
Section B; Preset Water Flew (gpm)
_"0utlet Gas" Temp. (BF)
Bed Diff. (in. H20}_ :11"_
Demister Diff. (in. H?6)~l
_RH Diff. "{{n;H2b)
_LlฃL
y.o
>-?
Comments
Gas Outlet Flow (in. H20)
-f.T
o
c)
-------
CHEROKEE STATION UNIT 2 DATA SHEET
A-ll
Date:-
Tlme:
Plant
Mw, Gross
XS P2 - - ,
team_Flow flbs/hr)
_J:jeam__Pre~s;sure (psig)
^team Temperature (ฐF)
Opacity, Bypass (fl
ESP
Section A'T-A2T^C~V^a'ge (v)
3RC"Current (a)
DC Voltage" (Kv)
"BC'Turrent (ma)
~5parFRaฃe" (spm)
SprHoii A3-A4; AC Voltage fv)
ftC.Current (a)
J3C Voltaqe
DC Current (ma)
"Spark Rate (spm)
Section B1-B2; AC Voltage (v)
" " -'.(a)
AC Current
Section R3-B4; AC Voltage (v
AC Current (a.
DC_yo) fage" (Kv)"
DC_Cufr^nt_ (ma)"
!~(spm;
Spark rate
_SectionJtb C2L.AC ..Vol.ta ge
AC Current
DCJolJtage.
DC Current
Spark rate"
Serti
-------
A-12
CHEROKEE STATION UNIT 2 D<\TA SHEET
Date:
_Time:
Plant
Kwป. Gross .
XS Oz
Steam Flow (lbs/hr)
Steam Pressure (psig)
team Temperature (ฐF)
Opacity, "Bypas's'(X)
870
(<&c
/OOP !
J5CE/LJC/0
.ESP '
..Section A1-A2;
AC Voltage
AC Current
DC Voltage
DC Current (ma)
Spark Rate'(spm)
a
Kv]
>i&-/*<> .
i -f 1 i
:!r
v
a
Kv
ma
spm)
Section
-Section
;. AC Voltage (v)
AC Current (a)
"DC Voltage (Kv)"
DC Current (ma)
Spark rate (spm)
AC Voltage
AC Current
DC Voltage
DC Current
Spark rate
(v)
(a)
(Kv)
(ma)
(spin)
Section 63-C4;_AC .Voltage.JvJ __
__ AC Current (a)
_". . ".. DC. Voltage (Kv
DC Current"0na)
Spark Rate (spm)
i 340
4?
34j
330
o/o
. 0<4T. ..
J/o/xto. ,i4c/!3.&
.&'/3~if
.33.0
70-tlO ..
.*/3l . .
..3$:^ .: . .._
; o
'i&ol, ._"
.i_^i_:
JV^' -
:r^> ;
. /o
_. . Section 01-D
Section D3-
J(C Voltage*{v)
Curr^rtt (a)
!Kvi
(ma)
Spark R&te (spm)
Comments
-------
CHEROKEE STATION UNIT 2 DVTA SHEET
A-13
nปtp-
Time:
Plant
FJC.I
MM, Gross
XSO?
Steam Flow (Ibs/hr) x e*
Steam Pressure (psig)
Steam Temperature (ฐF)
Opacity, Bypass (%)
ESP , .
Section A1-A2; AC Voltage (v
AC Current (a)
DC Voltage (Kv)
DC Current (ma)
Spark Kate (spm)
" BJ-BA. .
SprHon AVA4; AC Voltaqe V)
AC Current a)
DC Voltaqe (Kv)
DC Current (ma)
Spark Rate (spm)
Action M-&2: AC Voltage (v)
AC Current a)
DC Voltaqe Kv)
DC Current ma)
Spark Rate spm)
SPcH"" R*-B47 AC Voltaae v|
AC Current a)
'3C Voltage (Kv)
DC Current ma)
Spark rate spm)
fii Ii4-
Cerflnn M=ฃ2: AC Voltaqe v)
AC Current a)
DC Voltaqe Kv)
DC Current ma)
Spark rate spm)
<; orf inn r.i-r.4; AC Voltage (v)
AC Current (a)
DC Voltage (Kv)
DC Current (ma)
Spark Rate (spm)
Sertlan- Dl-OZ-t AC Voltage tvl
ACsCurrenjfex'(a)
DC Vott-iae (Kv)
nc Gtjrrent^ima)
Spark Rate (spm)
fnrH nn-rn-fM 'AC^Voltage^fv")
AC Our rent ( a J
DC Vo^wqe (Kv)
Spark Rate (spm)
ff/P/77
/coo
^loj'"
^ -r
tf-TO
,44r~)
;Oฃ,T
tz.
2He^i-c.l
>** -4>
3S/-5P
7n/&(J
3-//.0
.?CO
"?r>
tf /**
/os/t-z
0/0
ซ-
'f-j
f) 4-
?o i-/L-,i
o/o
1
i>c,
' J'j~/?4-
/'-70
O
2to*=lC
, -^Ot,ft
. ^2/a'^
1 ^.Vl-
O
-*?-^
' 3-,/iT.
-Jtfi?
/O
i
1
5A/77
/a4i
'T,^0
-? 2.
eco
*/li/\
1 (J&&
(3.
5ฃฃ?'-<->
9ซji4-
?vA-r
(_n/tn
4 =/>-
2
re
Vi /~&-
gt, A-
o/o
TV
'"I
f>- .f
rt-/<-,n
"/O
2OO
4ซ
i4/z.^
/CO
0
".Z^tlfc,
vv.rr
.1l /-if
VWCVJ
0
-^,0^20
>c"t-c-
3 ป/JO
p(ij!iL4e
.qW?;
) 3.-?t
7'3^*
3.4
J'L^'
i-fln
9ซiO
,.ซ.
?fio-4o
^TStป"
.7P /?P
| IO /I iD
z^y. o
?,-,rs
..IS
31 /Vs*
/
'6/0
-74o
^-,
0 )T
^5*f /TP/
0/6
7-20
>"ป
?4/7C
( 7c>
o
-,0-tjc
70^:5-
?ฃ>/7O
40C
0
>no-io
-y^T^'
i"?/?^
^/r>^Jฃ
JO
tt/?A->
/Oft-2
y^iyisro
lOp>
f?CO
/44r>
*/g-r
7.7
Jปr^-SO
,, , ^.5"
ซ.-iV?s-
tS'/S~
70f-
^4-
^ftA^
liป/,IO
o/b
?-^
V7
O,.t-
,^^/q^
ซi/o
2/0
i~O
^T/T^-
/e*O
0
2Z<*io
7a-ClC5
.7V/-7,
3^to
0
2lo
"70
JTJ/S3
(7.-T
" 1ฐ
'
i
j
*
i
(
J
Comments
-------
A-14
CHEROKEE STATION UNIT 2 D
-------
CHEROKEE STATION UNIT 2 DATA SHEET
A-15
Time;
SEffi
'/34o
//GO
Plant
FUEL.
75'fl.Co.H.
Co?6
Mi*. Gross
_XS 02 , _
Steam_Flow (lbs/hr) _
S.team_Pressure"(psigl
Steam Temperature (BF)
/oz.
*'0
3/0
/
-------
A-16
CHEROKEE STATION UNIT 2 DATA SHEET
Pate;
Time:
PI ant l-uฃ(^.
Mw, Gross
XS 0?
_Steam Flow (lbs/nr) x/o *
Steam Pressure (psig)
Steam Temperature (ฐF)
Opacity, Bypass (%)
ESP ' *ฐ^
Section A1-A2; AC Voltage (v)
AC Current (a)
DC Voltage (KV)
DC Current (ma) A
. Spark Rate (spm)
Kl -Kl
vf f/t-
SpeHnn *3=S*: AC Voltage (v)
AC Current (a)
DC Voltaqe (Kv)
DC Current (ma)
Spark Rate (spm)
Section &&F2- AC Voltage (v)
AC Current (a)
DC Voltaae (Kv)
DC Current (ma)
Spark Rate (spm)
^Hon '8335; AC Voltaae (v)
AC Current (a)
DC Voltage (Kv)
DC Current (ma)
-, .. Spark rate (spm)
K+- Kff.
$prtinn O33: AC Voltage (v)
AC Current (a)
DC Voltaae (Kv)
DC Current (ma)
Spark rate (spm)
Action C3-C4; AC Voltage (v)
AC Current (a)
DC Voltage (Kv)
DC Current (ma)
Spark Rate (spm)
sTfcuon D1-D2: AC Voltaae JvT
^\^ AC Current (a)
X, DC VoHage (Kv)
N. DC Current (ma)
Xsp'ark Rate (spm)
Jjectjon DS^IM' ACvVoltage (v)
/ AC Chrrent (a)
/ DC VorVaae (Kv)
/ pr Current (ma)
/ Spark Rate\Upm)
ws/n
^C& Cef
t/t>
3?F>
5?"7t?
/4-3-O
/OCD
/Ms
.3&D
"5 X
*4/.W
'9$feaa
o/f
i
j>g
^frjat^1
lko//4<.
6{o
340
OUT
fif/tfo
O/o
I
Tt^Zktj
si
Xt/lt
ftoO
O
?
ouT
IfS/rto
O/O
Jjf
3 O
fp
tfojfn
cJ'/3a
~7&l Cc.
<$- ~fป
lo/O
ajf'fr
^.25
*S7
3<*/3l
Ciff/flC
to/?
ZL0
TO
fO/eld.
Ibf/l4c
o'/ o
^4o
C^1
rmT
ftftf/fu
Of b
220
d?
4^/4-^
3 6O
O
^70
Oj /
t-r/iL-
ft
330
9/
32/32.
tCฃo
/f)
*L
ff
tfjulri
//OT>
7S"2, C.e.
/f$t
%ฃO
. 1-4-3-0
tftO
**%
3-4*">
*?H T
iq^/rtL
O/O
735-
-Tf
4Jf/4-(*
J.O&
o
J
>
i
;
i
i
i
1
Comments
7 1
- S rฃA /> /
-------
CHEROKEE STATION UNIT 2 DATA SHEET
A-17
Time:
Plant fZuฃ
!?>?. CtAt
', Itf.OU.
_MktปJGr.o$i
_XS.02
I /04
//r
_jteam_Flow (Ibs/hr)
_Steam_Pressure (pslg)
Steam Temperature (ฐF)
i*. J i.. Qiifi^^f f 9^1
*/--
Opacity, Bypass"(f)
/oaty
, /.3V,
"/c
/S'7e
3/t3
ESP
"' Section "A'l -A2T"AC' Vbl tage"
AC"Current
DC Voltage
DC Current
&I-A1
(v) -
!a).~
(Kv)
("*)-
^parFRate (spm)
^C-> L
_SectionJ5S^L-Aฃ_y.pl.tage.
AC Current
DC Voltaqe
DC Current
Spark Rate
Section B*=B2: AC Voltage
A_C_Current_
ฃ?n!
#cro/X.erD\
20V
(Kv)
(ma)
(spm)'
0/ฐ
3tf-r
JOi
i/70
M-
-(*',
(Kv]
ft* -Aฃ>
Spark
O
0(0
' our-
-------
A-18
CHEROKEE STATION UNIT 2 DATA SHEET
OatP- \V/JS/?7
Time: I ^>&3&
Plant ~uet~ ?*'%ฃซ,
Mw, Gross 1 ? f
XS 0? ^-5"
Steam Flow ^t>s/nr) ^^er
Steam Pressure (psig) /4-?ฐ
Steam Temperature ("f) qrgo
Opacity. Bypass (%) /3-A
Section A1-A2; AC Voltage (v) *- ^7^?
AC Current (a) J ' ?*}
DC Voltage (Kv) 4e/4a
DC Current (ma) 3en/j./o
Spark Rate (spm) o
Action A3-A4; AC Voltaqe (v) l(n>
AC Current (a) J'?_J
DC Voltaqe (Kv) Jy/i?
DC Current (ma) Ho/tyo
Spark Rate (spm) Q^
Section B1-B2: AC Voltage (v) pfo
AC Current a) $i,
DC Voltaqe Kv) OUT
DC Current ma) Jovfilo
Spark Rate spm) , ^j
?prHon B3-B4: AC Voltaqe (v) ' -3X0
AC Current (a) 5*j
DC Voltage (Kv) ftna)
X Spark Ra^ (spm) .
CnrHon 07-IT4V ACXVOl taqe (v) 1
S&, Current (a)
/ DCSVoHaqe (Kv) .
.^ PC Oirrent (ma)
./ SparkSiate (spm) 1
<^&3
'd
*
it
y
t
.
ir/jffi}
orio
~}$% (.V*
//^
^5T
94O
14,3.0
/ &OO
JLoX
3b&
^4,
40/4-0
Ifj//t0
f/r
7(713
f^f
;^-/^9
* f
h/b
JfO
ฃ~b
auT
poo/ito
0/0
fatlo
4-S/4I
JSO+Jti
o
yfytfO
7ฑtฃO
3b/yfc
Vf4O tฃ0
0
jj-O
12-
3b/4b
5JO
/o
'
r
i
1
J
1
1
1
|
I
|
1
Comments
rW
-------
CHEROKEE STATION UNIT 2 DMA SHEET
A-19
J1roe:_
Plant
/020
_Hrf*_GroSi
XS 0ฃ ..,_
~Steam_Flow_Obs/hr) ">. icy3"
Steam Pressure (psig)" "
SjteanL.Terapera_ture (3F)
Opacity, Bypitao (?)
' "*
2-7
1.7
ฐi JO
/OOO
550
72.0
/csy
r
* o
J-O
Mi.
CJP
SectioFAi-AfrAC'Vdltage-(v)
AC Current (a)'
~DC Vol tage" (Kvl
DC Current fma)
Joo . 3!j
~iM!,
,- A,.
.',.1
~Sp a r (TRa te" (s pm) r,/.f
'-"> -'.-I jo/ro
&- ---
-SectlonJtt&ttLtfL Vol taqe
3-
230
43
AC Current
DC Voltage
DC Current ( .
"Spark Rate (spm) " q/^ i c/ฃT~r Q/Q
"&~5 x;.:. I.MO/J70
0? /, ?
o/s-
2.70
4-L. .
_Sectjon BT=62: AC Voltage
AC_Current
(v)_
()._.
DC .Vol taqe. (Kv) ...
DC_Current (ma) _
"Spark Rate" (spm)
z4o
^ 1 C3/0 ! 0/0
ZO1
_1_1QQ.
o
ip:1
Voltage
AC Current
-i;
v)
.a)
"DC" Voltage (Kv)"
"DC! Current (ma)
Spark "rate"(spm)
"
^&_
r~^'
J^-P^
_Sectum_fee2:.AC Voltage
AC Current
DC .Vol tage
DC. Current.
Spark rate
0 0
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spm)"
' o
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AC_Cu rrent
DC Voftage"
v!-
a).
13
30/2.
t?
_7
26.0
iz.
DC Current', .
Spark Rate (spm)
3&/IB
io
(0
30
10
3
AC Current (*) _ ,
DC Vgltjgo (Kv) " ' ""
IDC..Current.(map "~ I
**
SocJiian-D3 D4-I.AO Veltago._M_
_AC Cuiipent (n)_
DC Volt390-(.Kv)
_DC Current (m,
Sparlt Rate
^T:::
-i
Comments
-------
CHEROKEE STATION UNIT 3 DUTA SHEET
A-21
Date:
'Time:
Plant"
Mw, Gross..
_XS 02
"Steam FloV(1bs/hr)
Steam Pressure (psig)
Steam Temperature (ฐF)
Opacity, Bypas* (%)
Opacity, Scrubber
JCI \lfl .
, fr^A.-seVM*
_ESP_ fc-b*
Section A^-A*i_AC Voltage
AC Current
DC Voltage
DC.Current (ma
Spark Rate (spm)
*(> AT. - - -
Section PKBฃ; AC Voltage (v)
AC Current (a)
... 14$; .
1&2..-T--41&
DC Voltaqe
DC Current
Spark Rate
Scrubber
Fans; Fan A Inlet Pressure
Fan B Inlet Pressure
Fan A Outlet Pressur
Fan B Outlet Pressur
Fan A Amps
. Fan B Amps
Stack Damper A, Pos.
Stack Damper B, Pos.
Kv) O
(in. H20) - / n
(in. H20) -S -tV '
ป (in. H20) -r*,ซJ /o s-
8 (in. H20) _-?/j _yu^L
22ฃ> '-(?<^
-*it> tJt?
(X Opn) o o
(% Opn) * 3 " o
aff~ ซ*> j ปN tJ > (}
(^ r^ I 10
"sYo cm 5*/o i S'iO ' <3cj ' s$e> '
C> y ** ' ฐ ฐ ฐ
! ^f ^: ^ ' t i
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-------
A-22
CHEROKEE STATION UNIT 3 DATA SHEET
Date:
Time:
Plant
Mw, Gross
XS 02
Steam Flow (Ibs/hr)
Steam Pressure (psig)
tin*
LOAD
*'<>
'
KM
\OSO
1030
Steam Temperature (ฐF)
Opacity, Bypass-(*i
ESP
Section A1-A2; AC Voltage
AC Current
DC Voltage
fUC
(x
ffl
(Kv)
ten
0
51
>opo foro
DC Current (ma)
Spark Rate (spm)
SO
100
X
s-o
10
?
SD
y
fO
9i
?
S.S
-y
. fe.
Section B1-B2; AC Voltage
AC Current
DC Voltage
DC Current
Spark Rate
v)
a).
Kv)
ma)
spm)
Scrubber
Fans; Fan A Inlet Pressure (in.
Fan B Inlet Pressure (in.
H20)
H|O)
no
no.
no
no
0
no
4o
too
o
o
no
40
no
,oi ..
/
/o8
Fan A Outlet Pressure (in. H20)
Fan B Outlet Pressure (in. H20)
Fan A Amps
Fan B Amps
Stack Damper A. Pos. (2 Opn)
Stack Damper B, Pos. (% Opn)
Pumps:
Recirc.
Recirc.
Recirc.
Recirc.
Recirc.
Pump Al (Amps
Pump Bl (Amps
Pump B2 (Amps
Pump B3 (Amps.
Pump Cl (Amps
Reheater; Steam Flow (M Ibs/hr)
Steam Temp. (ฐF)
Steam Pressure (psig)
'Section A; Presat. Water Flow (gpm)
Outlet Gas Temp. (ฐF)
Bed Diff. (in. H20)
Demister Diff. (in. H20)
RH Diff. (in. H20)
.flaa Outlut.riowJla^ilzQ)
Section B; Presat. Water Flow (gpm)
Outlet Ras Temp. (ฐF)
Bed Diff. (in. H20)
Demister Diff. (in.
RH Diff. (in. H20)
6as~6ut-1ot F-Tow (4ti
Section C
Presat. Water Flow (gpm)
Outlet Gas Temp (ฐF)
Bed Diff. (in. H20)
Demister Diff. (in.
RH Diff. (in. H20)
RH Diff. (in. H20)
Bas=OW*et-ซe*^fn
H20T
:7
- ^.
"H
Comments fc/i/
7i -
ซ>A/ t
-------
CHEROKEE STATION UNIT 3 DATA SHEET
A-23
Date:
Time:
Plant
Mw. Grass
XS Op
Steam Flow (Ibs/hr)
Steam Pressure (psig)
Steam Temperature ("f]
Opacity, Bypew (I)
ESP
Section A1-A2; AC Voltaq
AC Curren
f"
R
e
t
DC Voltage
DC Current
Spark Rate
Section B1-B2: AC Voltaq
AC Currer
DC Voltao
DC Curren
e
t
e
t
Spark Rate
Scrubber
Fans; Fan A Inlet Pressure
Fan B Inlet Pressi
Fan A Outlet Press
re
ur
0-*
rftf
iij * n>
B/ft/71
/o/4-
il-}
7
TO
'ftCC
/oco
C>
&ซ-i
/
v) '" ' /
a)
Kv)
ma)
spm)
v)
a)
Kv)
ma)
spm)
(in. H20~)
(in. H20)
s (in. H20)
&t>
ซ/ซ/6?'
itKl
"3/3 /?7
}*'(
l\*r 13-7
/.^
?"?
/"/^
yiv
2.2
yftco ^_tB&ฃ? )&nrt
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O*.i ,7s-0./y^T7'ซVflปซ-
uo it,y
to ' ItO ?Zo
l,t&
->?f*
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4f ' 4/ '4( ' 4">
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-------
A-24
CHEROKEE STATION UNIT 3 DATA SHEET
Date: . */6/77
Time: )33f
Plant
MM. Gross
XS Op
Steam Flow (Ibs/hr)
Steam Pressure (psig)
Steam Temperature (ฐF)
Opacity, Bypaoc (%)
Duality. sVrubbcr (t) &
CB^A/
^ป*i !
,
_.ff
J&<- _^ _
\x/bhi\ 'W~n
i
DOWA/ i /3f
: e?. 5
IO50'
JX&O
' /&&&
. - i /ฃ-
"SUJt, (ex
NflT- QA) At.fi <* Sc/V/ V 10' \ \ /ฃ&
ESP ' . ! !
Section A1-A2; AC Voltage
AC Current
DC Voltage
v) < J4o
\qli(lT\ \
\j34*r~
r
a) ' -is* ~s
Kv) 40 i
DC Current (ma) TOO :
1~ ' '
*7l o
ilTirv :
/ffW '
t4- i
stftCt*^ :
5*0 \ 9 ,
%4f ' 1 ' '
j&ff/3.6
*ho
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-------
CHEROKEE STATION UNIT 3 DATA SHEET
A-25
Date:
'Time:
"Plant"
ft*. Gross
XS 02
Steam Flow" (Ibs/hr)
Steam Pressure (psig)
Steam Temperature (ฐF)
Opacity/'Bypass (%)
Opacity, Scrubberl*) ฃuฃ<-
L __#ฃฃ
J30
J70Z~
7-T
n?4
_ฃ3ii:;
ESP
~_Section_Al;A2; .AC Voltaqe
AC Current i
- DC Voltage
' DC. Current
Spark Rate
!
v) ----
I. ~-'~~i
/tiro
~3iz
Kv)
uia)
spm)
.702-
'_ZQ.
740
(, 3?
IO
if6*100*
t4l&&0.J.Mฑฃฐ
_.Sect1o.n_BJL-B2.;. AC .Vol tage
AC Current
.DC Voltage
DC Current (ma)
"Spark Rate (spm)
v) 1
a) r
310
/*f
ll
-------
A-26
CHEROKEE STATION UNIT 3 DATA SHEET
, /
Date:
"Time:
'Plant
_tt*. Gross.
_XS02
.... Steam Flo"w"(1bs/hr) ~
Steam Pressure (pslg)
Steam Temperature (ฐF)
Opacity,
Opacity, ScruDber-fi) i=ujti~
ESP '?*? _
Z_ "Section_ANA2;_AC Voltage (v) _ "_" 3}0f7o '.
AC Current (a)
___- DC Voltage (Kv)
'_ ~ DC. Current (ma)
Spark Rate (spm)
Section B1-B2; AC Voltage (v)
_AC Current (a)
__DC Voltage (Kv)
_DC Current (ma)
~Spark Rate (spm)
Scrubber
F.ans; Fan A Inlet Pressure (in. ^0)
Fan B Inlet Pressure (in. H20)
Fan A Outlet Pressure (in. H20)
Fan B Outlet Pressure (in. HzO)
Fan A Amps
Fan B Amps
Stack Damper A, Pos. (Z Opn)
Stack Damper B, Pos. (1 Opn)
Pumps: Recirc. Pump Al (Amps)
Recirc. Pump 81 (Amps)
"Recirc. Pump B2 (Amps)
Recirc. Pump B3 (Amps)
Recirc. Pump Cl (Amps)
Reheater: Steam Flow (M Ibs/hr)
Steam Temp. (ฐF)
Steam Pressure (psig)
Section A; Presat. Water Flow (qpm)
Outlet Gas Temp. (ฐF)
Bed Diff. (in. H20)
Demister Diff. (in. H20)
RH Diff. (in. H?0)
Gas Outlet Flow (in. H2ti)
Section B; Presat. Mater Flow (qpm)
Outlet r,as Temp. (ฐF)
. Bed Diff. (in. H?0)
Demister Diff. (in. H^O)
RH Diff. (in. H?0)
Gas Outlet Flow (in. H20)
Section C; Presat. Water Flow (gpm) .
Outlet Gas Temp (ฐF)
Bed Diff. (in. H?0)
Demister Diff. (in. H?01
RH Diff. (in. H?0)
RH Diff. (in. H?0)
Gas Outlet Flow (in. H20)
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Comments
-------
CHEROKEE STATION UNIT 3 DATA SHEET
A-27
Date:
"Time:
"Plant
H*, Gross
XS 02
"Steam Fl6w~(lbs/hr)
JSteam Pressure (pslg)
"Steam Temperature (ฐF)
Opacity. Bypass (ฃ)
Opacity, Scrubber (%)
._ .
_ Sectl.on..AlzA2; _AC Vol taqe
AC Current
- DC Voltage
~_ DC..Current
Spark Rate
_ Section_BJb_B2j_ AC. Vol tage
AC Current
DC Voltage
DC Current
Spark Rate
_Scrubber . .
_F.ans; Fan A Inlet Pressure
Fan B Inlet Pressure
Fan A Outlet
Pressure (in
Pressure (in. HgO)
Fan B Outlet
_Fan A Amps
_Fan B Amps
Stack Damper A, Pos. (Z'Opn)
"Stack Damper B, Pos. (
Pumpsj_Recirc._Pump Al (Amps)
Recirc. Pump Bl (Amps)
^"Recirc. Pump B2 (Amps)
Recirc. Pump B3 (Amps)
'Recirc. Pump Cl (Amps)
_Reheater; Steam Flow (M Ibs/hr)
Steam Temp. (ฐF)
Steam Pressure (psig)
Section A; Presat. Water Flow (gpm)
'Outlet Gas Temp. (ฐF)_
Bed Diff. (in. H20)
Demister Diff. (in. H20)
RH Diff. (in. H20)
Gas Outlet Flow (in.
JSection B; Presat. Water Flow (gpm)
Outlet r,as Temp. (ฐF)
Bed Diff. (in.
Demister Diff. (in. H20)
RH Diff. (in.
Gas Outlet Flow (in.
Section C; Presat. Water Flow (gpm)
_ Outlet Gas Temp (8F)_
Comments
Bed Diff. (in. H20)
.Demister Diff. (in.
.RH Diff. (in. H20)
.RH Diff. (in. H20) _
Gas Outlet Flow (in.
-------
A-28
CHEROKEE STATION UNIT 3 DATA SHEET
Date:
Time:
Plant
MM. Gross
XS 0?
Steam Flow (Ibs/hr)
Steam Pressure (psig)
Steam Temperature (ฐF)
Opacity. Bypass (%)
Opacity, Scrubber (%)
ESP
Section A1-A2: AC Voltage
AC Current
DC Voltage
DC Current
Spark Rate
Section Bl-B2j AC Voltage
AC Current
DC Voltaae
DC Current
Spark Rate
Scrubber
Fans; Fan A Inlet Pressure
Fan B Inlet Pressure
v) .. "
a
Kv)
ซa) ""
spm)
v)
a) ' ~
Kv) . ..
ma)
spm)
(in. H20)
(in. H20)
Zfos/t
fxJto
ฃ>CtT
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Fan B'Outlet"Pressure (in".
Fan A Amps
Fan B Amps
Stack Damper A, Pos. (% Opn)
Stack Damper B, Pos. (1 Opn)
Pumps; Recirc. Pump Al (Amps)
Recirc. Pump Bl (Amps)
'Recirc. Pump B2 (Amps)
Recirc. Pump B3 (Amps)
Recirc. Pump Cl (Amps)
Reheater: Steam Flow (M Ibs/hr)
Steam Temp. (ฐF)
Steam Pressure (psig)
Section A; Presat. Water Flow (qpm)
Outlet Gas Temp. (ฐF)
Bed Diff. (in. H20)
Dcmister Diff. (in. H?0)
RH Diff. (in. H?0)
Gas Outlet Flow (in. K20)
Section B; Presat. Water Flow (qpm)
Outlet tos Temp. (8F)
Bed Diff. (in. H?0)
Demister Diff. (in. Hj>0)
RH Diff. (in. H?0)
Gas Outlet Flow (in. HgO)
Section C; Presat. Water Flow (gpm) ..._
Outlet Gas Temp (CF)
Bed Diff. (in. H?0)
Demister Diff. (in. H?0)
RH Diff. (in. H^O)
RH Diff. (in. H?0)
Gas Outlet Flow (in. HjO}
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Comments
-------
CHEROKEE STATION UNIT 3 DATA SHEET
A-29
Date:
Time:
Plant
Mw"! 'Gross
XS 02
Steam Flow (Ibs/hr) vl(
Steam Pressure (psig) ^
Steam Temperature (ฐF)
Opacity, Bypass (%)
Opacity Srruhhpri (ilr}-/--v
ESP
Section A1-A2; AC Voltage
AC Current
DC Voltage
DC Current
Spark Rate
r_ *.ฃ__ Dl OO . A/* tlnlซ.i*.j%
&M/T1
IfJIft^
,40
2- 1
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1
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a) nta
Kv) 37
ma) $10
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AC Current (a)
DC Voltage (Kv)
DC Current
7.30
i !.?_
_LSi.
Spark Rate
__Scrubber
_F_ans; Fan A
Fan B
Fan
Fan
Inlet Pressure (
B Inlet Pressure (
A Outlet Pressure
B Outlet"Pressure
_Fan A Amps
Fan B
Stack
)
m)
iT." H;O)"~
n. H20)
in. H20)
in."H20)" '
-?4f> -/so :
0 | 0 , ,
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Damper~A, Pos". (t Opn)
"Stack Damper B, Pos. (% Opn)
I
-i 1..
Pumpsj Reel re. Pump Al (Amps)
'_ ^Recirc/Pump Bl (Amps)
"Reelre. Pump B2 (Amps)
Recirc. Pump B3 (Amps)
""Reelre. Pump Cl (Amps)
Steam Temp. (ฐF)
Steam Pressure (psig)
Section A: Presat. Water Flow (gpm)
Outlet Gas Temp. (ฐF)
Bed Diff. (in. H?0)
Demister Diff. (in. H20)
RH Diff. (in. H?0)
Gas Outlet Flow (in. H2fl)
Section B; Presat. Water Flow (gpm)
Outlet r,as Temp. (ฐF)
Bed Diff. (in. H?0)
Demister Diff. (in. H?0)
RH Diff. (in. teO)
Gas Outlet Flow (in. H20)
Section C; Presat. Water Flow (gpm) .
Outlet Gas Temp (ฐF)
Bed Diff. (in. H?0)
Demister Diff. (in. H?0)
RH Diff. (in. H?0)
RH Diff. (in. H?0)
Gas Outlet' Flow (in. H20)
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CHEROKEE STATION UNIT 4 DATA SHEET
A-31
Jate:
Time:
lant
I**, Gross
-xs-o2-
_Steam_Flow_Obs/_hr)
Stpam Pressure (osl
osiq)
Steam Temperature (ฐF)
Opacity ซ_Bypass_lX)
Opacity. Scrubber (36)
ESP
Section AT; AC Voltage (y)
AC Current .... ,
DC Voltage (Kv)
DC Current (ma)
Spark Rate (
Section A2; AC Voltage '
AC_Current
DCJ/oltage
__:DC Current xป~,
Spark. Rate_(spm) ;_.
.Section A3; AC Voltaqe
AC Current
DC Voltage
vY
DC Current (ma}
Spark Rate (spm)
Section A4; AC Voltage.
AC Current
DC Voltage .
DC .Current.
Spark Rate
.Section_Bimc_yo.l .tage_( v).
_AC Current (a)
_DC_Vo1tage_ "
_D"C Current
Spark Rate
_Sectian_B2; AC Voltage
AC Current .
DC Voltage (Kv)
DC Current \ '.
Spark Rate (spm)
-Section.B3;.AC.Voltage
AC Current
^DC Voltage .
- DC Current (ma)
1 Spark"Rate (spm)
Section B4; AC Voltage (v)
" AC Current (a)
~ " DC Voltaqe
DC Current
Spark Rate
KV) r -1
ma) ~_" ~~~T
spm) - ~1
-------
A-32
LHhKUUtt 5IAI1UN UN II ^ UMIft SME.C, I
(continued)
5crubber_..
Fans; ID.Discharge Pressure (in. H20)
Fan & Outlet Pressure (in... H20)
Fan C Outlet Pressure (in. H20) \J
_Ean._a_ Outlet Pressure (in. H20) ._iY.i.
.Fan.ji_ A"1?5 --
OiJT
Fan ._c-J.Amps ._ ...
Fan to .Amps _.
itack..Damper_A._Pos.._(_ (ton).
Stack Damper B. Pos. (1 Opn)
PjflBP_s.i_Rec1rc...Pump_ B( (amps;
Z4-U ! g4t3
JJecirc. .Pump
Reci re...Pump
Recire. Pump p(
amps,
amps
amps!
iRecirc. Pump g.z. amps!
Reci re. Pump gj. (amps
"Recire. Pump a, (amps
lH.Recirc. Pump ex. (amps
43L
H.
O ji-
-lxฃ-\~
-t
2 -SO i'
c?
.4-
ซ-*:
-2.LQ-
zz-o
^ 2
Ji .
/a i
"Recircr Pump D5> (amps)
Reheater; Steam Flow (M Ibs/hr)
Steam.Temp. (ฐF) 1
Steam Pressure (psig)
Section B ; Presat. Vlater Flow (gpm)
Out.letJ?as._Temp. _(ฐF_)
Bed Diff. (in. H20)
Demister Diff. (in. H20)
______ __ IRH Diff. (in. " "%
__ฃZ_L-i.ฃฃ...
.__{^eso.- 2/Q
.Section.._t._;.Presat Water Flow (qpm) i
Outlet fas Temp.
..Bed Diff.. (in. .H20)
Demister Diff. (in. H20). _
._.RH Diff..(in.
M tin H2gi
ฃvฃ3S.4iฃ.:J
.Section...&_.;.Presat. Water. Flow (qpm).
/ Pr,
Outlet Ras Temp. (ฐF) _ ^c
.Bed.Diff. (in. "
_Dem.ister_.Diff_(in. H20)__._
JIH Diff. (in. H20) _j_
fias-Xtutlet-How (in.-HgO)
I^Ll 3TftOv>. k-ESS Cf:\\
! /->
31 O
. \
Oo t-
.24S_1_13.>
--&-! 8
'4,
/<--
O.fo
.iiiaJ-j-TT
_^3L
7ฐ
C> . i
2.0
_4i...
/). JT
/so
-2vL
./*....! i3>_
t| //
4- ...4i/--.
-ฑ::.
iT I
-//.-y-
-;2- -
i - .
r 74sc"
la-? i /ฃ?<
JJ3.1 . ..'o^. .
_Hc__a ?4_<3.,
S.0 :. ^Q. _
g,"? ' Q,>
t-
o. .
-- !
res-
m
L p.V ..
. ._ซa
.0 C-
Comments
-------
CHEROKEE STATION UNIT 4 DATA SHEET
A-33
Date:
Time:
Plant
Hw, Gross (ซซซ">
/ XS Oy
j, Steam Flow (Ibs/hr). x/o*
_ Steam Pressure_(psiglx/oB._
Steam Temperature (ฐf)
. .Opacity, Bypass .(56)^/45
Opacity, Scrubber (%)
a/n.
ESP
Section Al;
__ _
.
.Section A2;
- -
Section A3;
Section A4;
. Section Bl ;
_ Section 82;
'. ."
AC Voltage
AC Current >
DC Voltage
DC .Current, i
Spark Rate i
V
a)
Kv)
ma)
spm)
AC Voltage (v)
AC Current (a)
DC Voltage (Kv)
DC Current
Spark Rate
AC Voltaqe
AC Current
DC Voltage
DC_Current
Spark Rate
ma)
spm)
v)
iy
Kv)
ma)
spm)
AC Voltaqe (v)
AC Current
DC Volta.ge
a)
Kv)
DC Current (ma)
Spark Rate (spm)
AC Voltage
AC Current
DC Voltage
DC Current
Spark Rate
vJ
a
Kv)
ma)
spm)
AC Voltage (v)
AC Current (a)
DC Voltage (Kv)
DC Current
ma)
Spark Rate (spm)
- Section B3; AC Voltage
_ AC Current
DC Voltage (Kv)
_ DC Current (ma)
Spark Rate (spm)
i_Section B4; AC Voltage v)
AC Current a)
DC Voltaqe Kv)
DC Current (ma)
Spark Rate (spm)
3-6.
2-300
2000
! 34* '
, L
Z360
1050
4.6
~r
. ---- 770
132 -ป:_.!. 23^..
-!?70 1 "770
/4-0
OUT
&tL-
"jo
foot f o
0uT
lo '
TO
>.o4_. 1
OUT"
<ปt30
OUT
f-s"
OUT
fc>*i~
OUT
3fDtLฐ
Our
270
^(0 . 270 -(0
boo
OUT
bti
. Iff
our
300
30
3ooฃtO
70^/0
Jo
300 - to
45
70 i 75-
- S.O . 51
. __ 3o.o.
\ . _.: i
-------
CHEROKEE STATION UNIT 4 DATA SHEET
A-34
(continued)
Scrubber
Fans; ID Discharge Pressure (in. H20)
Fan _3_ Outlet Pressure (in. H20
Fan JL_ Outlet Pressure
Fan 0 Outlet Pressure
Fan "5" Amps x to
Fan _C_ Amps * ,0
Fan Q Amps * \ o
(in. H20
(in. H20
'-0.7*
0ttT
i ป""
i / (amps
Recirc. Pump Q; (amps
Recirc. Pump 01 (amps
Recirc. Pump D-J (amps!
>pn)
>pn)
23
O
O
13 .
/I
j.i..
Reheater; Steam Flow (M Ibs/hr)
Steam Temp. (ฐF) " '
Steam Pressure (psig)
/
4-5
its
0.8 .
Presat Water Flow (qpm)
Outlet Gas Temp. (ฐF)
Bed Diff. (in. H20)
Demister Diff. (in. H20)
RH Diff. (in. H20) c
GM-Outlet-FlowHin^HgO)
0,4
Section J) ; Presat. Water Flow (qpm)
Outlet r,as Temp. (ฐF)
Bed Diff. (in. H20)
. Demister Diff. (in. H20)
RH Diff. (in- H2Q)
Has -Outlet
ftO
tSS
5.4
Comments
- ฃ.
. l.
-o.f
OUT
10
3-1
O
G
JS"
.7, ^- s y ฃ. i ;.6
^?x/ 2.3
-O - O.
3 SO
/4o
8.0 7-t
i.O^.-.-O.'J -.-O.f . ..
i O O O
i8a Jiso
?_/?ป" . /fir. .
-------
CHEROKEE STATION UNIT 4 DATA SHEET
A-35
Date:
Time:
Plant
MM, Gross
XS 0*
- ' Steam Flow (Ibs/hr) y,J*
Stpam Pressure (osio)
steam Temperature (BF)
Opacity ..Bypass _(*)
Opacity, Scrubber (%)
ESP
Section Al; AC Voltage
AC Current
DC Voltage
v)
a) ..
Kv)
DC Current (ma)
Soark Rate (spm)
ฑzป-
:~v^~"
^co^J^
&A
^0*20
a) ' /.-TIP ' ,- e?-*ip
Kv)
DC Current (ma)
Spark Rate (spm)
i Section A4: AC Voltage
AC Current
DC Voltaae
DC Current
Spark Rate
_5ection BU_AC Voltage
AC Current
DC Voltage
DC Current
Spark Rate
_Section_B2; AC Voltage
AC Current
' DC Voltage
DC Current
Spark Rate
Section. B3 ;. AC. Vol tage
AC Current
DC Voltage
DC Current
Spark Rate
v)
a)
Kv)
ma)
spm)
v)
a)
Kv)
ma)
spm)
v) .__
a)
(Kv) *
ma)
spm)
Hr^-,^
/ .-rr/^
: rti.r ! o.jv i ~n ,-v
^40 .^z
i?/^"^K3
0-t
^
/ C?'*
1
1
210^2^'
CC1"- i
-53
24o-t -
, '
,
i
j
1
,
1
i
.
'
;
1
i
i
i
i !
i
\
rj
:
i
1
i
i
i
i
j
1
!
i
1
1
'
1
!
i i
-------
A-36
CHEROKEE STATION UNIT 4 UAIA bHLhl"
(continued)
Scrubber
Fans;. ID. Discharge Pressure (1r
Fan p Outlet Pressure
Fan <- Outlet Pressure
Fan p Outlet Pressure
Fan_ ^_ Amps
Fan.7o. .Amps
Fan ~ii Amps . ..
i. H20) .
In. H20)
In. H20) ^
in..H20) "
Stack Damoer A. Pos. (X Oon)
Stack Damper B, Pos. (% Opn)
Pumps: Reel re. Pump g[_ (amps)
Reel re. Pump ni (amps
Reel re. Pump ซ? (amps
Reel re. Pump c.t (amps
Recirc. Pump ^2 (amps
Reel re. Pump cv (amps
Recirc. Pump &, (amps]
Recirc. Pump rv, (amps
Recirc. Pump p,^. (amps]
- 4<-
~. i-
~ c.
O.JT ' Ou-i i rt.n-
rt * tin
I2.-T ! ll v."
2s-n
-M0)
^as-Out^t^-Flow^-i n,-H20 )
SectJon_j^;_Presat. Water. Fl
Outlet Gas Temp
ow (qpm)
(8F)
to . fco
,
l'*?" i 1^-faO
1
II..T
i f ."i
?4ซ,-
22. S-
1 ป'>
,
O M-
I/ .
// '"
^0
_,,.,-
r>*s.-
K-
1 ? S~ / 2S1
/.->*
o.^ : o.'r i 0-9
O o ft
Sio j 3iO ! -2.-10
/7~ 1-79
/7>-
/^"S" ' /ซ.X- /i"6
/A.L I i/t r.
/; C.
. .XZ.i_-
SUO
o---
<-?c
Bed Diff. (in. H?0) -7.4
npmistpr Diff. fin. H?0)
7 4-
DU niff. (in. n?n) r>
S-fซw prcv. t
/in UoH)
psc\\
4C.O
fc 2
^70 4tfc
l&f
/5ป.T
li^n \ Iff
r ,
O ^
no
^to
13
i 7 ซr-
,
il t>
.50
/4^o
/Bซf
^
I/.O
cj.'i
C5
3.70
/7S~
/^"O
//.O
rt.->T
O.I
47o
/P-T
J C.O
1
7. -2. '
2.2.
O
4,0
i
i
.
i
1
1
1
1
,
.
1
1
1
L .
-
Coranents
-------
CHEROKEE STATION UNIT 4 DATA SHEET
A-37
Date:
Time:
Plant
MM. Cross
|xs-o-f
.team.F!ow_[lbs/hr)
Steam,Temperature (ฐF)___y,_,
Opacijty..Bypass (%)
Opaci ty, 5&rubbor43)
ESP
,_Sect1on_Alj AC_Vo1tage (v)__ j?_/&
I AC Current (a) y^j i
_"DC Voltage (Kv) _ , oujr. .' r
_DC_Current (ma) &ฃt>*$~O i >
_Spark__Rate (spm)
_SectioiLA2i.JVC_Vo1.tage_(v) ,
AC. Cur rent (a) _ __
_DC Voltage
~DC Current
_Spark Rate.
Jectipn A3; AC Voltage (v)
AC Current (a)
..DClVoltage (Kv)
fiC_Current (ma)
Spark Rate (spm)'
Section A4; AC Voltaqe
_D.C Voltage
.PC Current
Spark Rate
^fiction.BluAC. Vol tage
AC Current
DC Voltage
DC" Current
Rate
Spark
,_Section..B2;.AC Voltage
i AC Current
DC Voltage (Kv)
DC Current (ma)
Spark Rate (spm)
_Sect1on_B3; AC Voltage .
AC Current (a)
DC Voltage (K
DC Current
"Spark" Rate
Section B4; AC Voltage
" AC Current .
DC Voltage (Kv)
._ DC Current (ma)
Spark Rate (spm)
-------
A-38
CHEROKEE STATION UNIT 4 DATA SHEET
(continued)
Scrubber
Fans; ID.Discharge Pressure (in. H20) __
Fan g Outlet Pressure (in. HgO)
.fan .ฃ_0utlet Pressure (in. H20) ;._
llan_*> Outlet Pressure (in. H20) j.
.Fan.To" Amps
Fan ฃ.. Amps _x./0 _.
Fan /) Amps ^ iO..
Stack Damper A, Pos. (X Opn)
Stack Damper B, Pos. (X Opn)
_P_ump.s.;. Reci re.. Pump . Bl (amps)
Reci.rc. Pump &L- amps)
Recirc._Pump //B amps"
Recirc. PumpCJXSf amps
_Recirc. Pump ci, (amps
I\CW I I \f m T UIII^T |/ fc- \ UIHK'
_Recir'c7"Pump c i (amps
Recirc. Pump pi
_2^_Recirc. Pump pz.
Re'circ. Pump jj
amps)
amps)
amps)
eheater;.Steam Flow (M Ibs/hr)
SteamJTemp. (ฐF)
Steam Pressure (psig) x/o2-
Section v \ Presat. Water Flow (gpm) . _
.Outlet J",as_Temp._(ฐF)_
.__. Bed Diff. (in. H20)
rซ ^. j. r\ฃ ฃ ฃ / J _
Demister Diff. (in. H20) _c
RH Diff. (in. H20) _P_u_r
Gas Outlet F-1ow ''
. .-5rA|-,
Section.A,;-Presat Water Flow (gpm) '._
__0utlet Ras Temp. (ฐF)
._Bed Diff.. (in. H20) l&SL
_Demister Diff. (in. H20)
RH Diff. (in. H20)
- ' " -Elow (in. H;0)
-&*.->
SectJon__P_i;.Presat. Water Flow (qptn) ...
Outlet Gas Temp. (ฐF)
Bed Diff. (in. H20)
Diff ...(in. H20)_.
JIH Diff. (in. H20)
f4
Comments
-------
CHEROKEE STATION UNIT 4 DATA SHEET
A-39
Date1:
Time:
Plant
MM. Gross
XS'O?
Steam.FlowJlbs/hr)_ .
team-Pj-.essure.Jp.slgl,
__Sleam.Temperature ("Fj
Opacity.. By pass _(ซ)
Opacity, Scrubber (%)
ESP
Section Al
AC_VqHage (v|
"AC Current (a)
DC Voltage (Kv} .
DC Current (ma) _
Spark^Rate (spm)
_SeclJon._A2i_AC Voltagejv) ' W>ฃ^
t (a) : [
_AC.Current , . .
.DC Voltage {Kv)
:DC Current (ma)
.Spark Rate.(
_Sectio_n A3; AC Voltage (v)
AC Current (a)
D"c:Voltage (Kv)
DC .Current (ma)
Spark Rate (spm)"
Section A4-. AC Voltage (v) ' 3#i
(a) ._. ; _
Kv)
AC Current
IDC .Voltage
.DC Current
"Spark Rate
_Sฃ.ction_Bl.:.AC..Voltage .(v).
AC Current (a)
Kv)
ma)
~DC_Vol tage
"DC Current
Spark Rate
_Section_B2;.AC Voltage
AC Current
DC Voltage
DC Current
'Spark Rate
_Section_B3;.AC Voltage (v)
AC Current (a)
DC Voltage (Kv)
DC Current
Spark"Rate
Section B4; AC Voltage
"AC Current
.DC Voltage
DC Current
Spark Rate
T/ty iitt^ TO
Sr>77
-------
A-40
CHEROKEE STATION UNIT 4 DATA SHEET
(continued)
/ /
Scrubber
Fans; ID.Discharge.Pressure (in. HzO)
- in.. H20)
Fan b Outlet Pressure
..Fan. ClJutlet Pressure
JEan ~5"~ Outlet Pressure
_Fan 3~~ Amps
in". H20) j .
In. HzO)
.Fan C. Amps
Fan o Amps
itack Damper A, Pos. (Z Opn)
Stack Damper B. Pos. (% Opn)
Pumps.;.Recirc.. Pump 6, (amps)
Recirc.. Pump _ฃj, (amps)
Recirc.__Pump yfo (amps)
Recirc. Pump c. (amps) JJ
Recirc. Pump c^(amps) ~
Recirc. Pump rป (amps) ""
Recirc. Pump p, (amps'
iซb w i t ซ i umr' tjf \ *aiiip* j /
_^_Recirc. Pump pi (amps)
Re'circ. Pump o* (amps)
Reheater: Steam Flow (M Ibs/hr) _ฃ>_
Steam Temp. (ฐF) '
"Steam Pressure (psig) _
.Section p ; Presat. Water Flow (gpm)
Outlet.Ras Temp._(eF) _
Bed Diff. (in. H20)
_ Demister Diff. (in. H20)
RH Diff. (in. " "'
Gas Outlet Flow (in. H20)
HH -' -
Section (L_\.Presat Water Flow (gpm) ... tfS- i_
Outlet Ras Temp. (ฐF)
_Bed Diff. (in. H20)
...Demister Diff. (in. H20)
._ RH Diff. (in.
' L noi
%
Section.^;.Presat. Water Ftow (qp'm) ._
Outlet Ras Temp. (ฐF)
Bed Diff. (in. H20)
Demister Diff. (in. HzO)
RH Diff. (in.
Comments
4
-------
CHEROKEE STATION UNIT 4 D4TA SHEET
A-41
-------
A-42
CHEROKEE STATION UNIT 4 DATA SHEET
(continued)
Scrubber
EansL ID. Discharge Pressure (ir
Fan Q. Outlet Pressure
Fan c. Outlet Pressure
Fan "p Outlet Prpซure
Fan_~5~ Amps ^ /O
Fan C Amps _x-/O
Fan p Amps ฃ / O
\ tf/sfn
i. H?0) i f-O. JL \
in. H?0 dc/r '
in. H20 'O.$ \
in. HZO 7.0 ,
J-3.
^ ^
Stack Damper A, Pos. (2 Don) ' O '<
Stack Damper B. Pos. (% Opn) . /j>
Pumps.; _Rec i re .. Pump . Si (amps
Recirc. Pump "TTv- amps
* |
I /^
/fc> !
Recirc. Pump /?/ amps) / 3 !
Recirc. Pump Q, amps
Recirc. Pump ^ amps
Recirc. Pump C* (amps
Recirc. Pump _g_,_ (amps
Recirc. Pump !
O
&6/7ฃ
L1 *y
<>ur
//' 5"
/c?.
3-D
al<&-
^- ^~
(2
O
/$ /i
/6 ! /(.,
/3 ;
/3
/3 ' /^i
14-
/4- \
/3
/ 3
id-
4&
'-~
teo
1 3
Iq.
f 3
13
>3
4^
i
I "
iff !
(ฐF) ih<; . - /so
Bed Diff. (in. H50) j, * 3, f \
Demister Diff.
in. H90) 0,7
RH Diff. (in. H?0) " O.* '
/?U_ rfrrt Pi
Section.C ;. Presat Water Fl<
Outlet Gas Temp
* Pi '2x' ^c"*)
? 1 l>^in ) tf^V ^ I.
4 U *'3 / j
3w (qpm) /7^
(ฐF) . /fctf ,
Bpd Diff. (in. HoO) ~7.-3 ,
0.1 "7
-~^
t7ฃ
i(t>(?
7.J.
Demister Diff. (in. H20) O.A \ \ O- -*
RH Diff. (in. H20) p^T ' ffnT,
GM-Outfril. riuw (in. HgO)
. jP.iJ iTiii ff_ CP(ffa) -%'O
Sectloru P ;. Presat. Water Flow (gam) lffฃ
Outlet Ras Temo
. (ฐF1 7fc/5
32 O
tST
tbo
Bed Diff. (in. H?0) ^.0 \ \ 4:0
Dpmistpr Diff. (in. H?0) , '/, / \ . /'3
>ปH Oi" (in "?01 . OUT n^T
P-kr r\iป*lAซ-. ClnM
An- ! i
/(a \
/j
/ฃ_ .:. _ .... ..
I
i^ \ \
\
/ rl'l '
/4-0
Iff? '
\ ne; ,
&ฑ
"~ฃฃ
(7i J-
f i~is=r
WO
\ i4'6
~if%~
J- G>
OL4T
/OO
/.? 1 |
/3 '
/ ^? j i ซ
<ฃ
O^T \
/0V
i
Comments
-------
CHEROKEE STATION UNIT 4 DATA SHEET
A-43
Date1:
Time:
Plant
iuzi_
MM, Gross
XS"0"2~
Steam.F.low_Llbs/hr)_ */&
.-Ei:es3ui:e_(pjigl,
Sleam Temperature ("fLl.
Opacity, Bypass (X)/^*
Opacity. Scrubber (%)^M
ESP
_Sectiqn_ A!. ;..AC_ Voltage Jvj__
~-. DC Vol tage (
._
AC Current
_DC_Cur.rent (ma) __<&&
_งpark._Rate (spm) [
_SecฑioaJ\2^AC_Voltage.
AC Current
_DC Voltage (Kv)
:DC Current (ma)
.JSpark.Rate, (spm) _
_Sjction_A3; AC Voltaqe (v)
'AC Current (a)
DC..Voltage (KvJ._
DC Current (ma)
Spark Rate
Section A4;
_A.C_Voltaqe
AC_Current
IDC .Vol tage
.DC Current
Spark Rate (spm)
.Section.Bl;_AC_Vol.tage. (v) _
AC Current (a)
DC Voltage (Kv)
PC"Current (ma)"
Spark Rate (spm)
Section.J2;..AC Voltage (v) _
AC Current (a)
(Kv)
(ma)
(spm)
"DC Voltage
"DC Current
Spark Rate
-Section_B3;_AC Voltage (v) .
_AC Current (a)
DC Voltage (Kv)
DC_Current (ma)
Spark"Rate (spm)
_Section_B4; AC Voltage
"__ AC Current
1_DC Voltaqe
DC Current
Spark Rate (spm)
A
-------
A-44
CHEROKEE STATION UNIT 4 DATA SHEET
(continued)
.Scrubber... .
.fans; ID.Discharge Pressure (in. H20)
Fan & Outlet Pressure (in. H20
.fan _ฃ_ Outlet Pressure (in. HgO
Ean.J2_ Outlet Pressure.(in. H20
Fan. A Amps V /Q
Fan. C. Amps _X iQ_
Fan _o_ Am?5 ^OO-. -
Stack Damper A, Pos. (% Opn)
Stack Damper B. Pos. (% Opn)
Lumps.;. Re.c ire ...Pump _B / (amps)
Recirc..Pump /;ป- (amps
Recirc._.Pump A > (amps
Recirc. Pump g,, (amps
Recirc. Pump c'i~(amps
ReciVc. Pump c., (amps)
"Recire. Pump j), (amps)
Recirc. Pump _ฃo_(amps)
Recirc." Pump ฃ>> (amps)
Reheater; Steam Flow (H Ibs/hr)
Steam Temp. (ฐF)
"Steam"Pressure (psig)"
Section & ; Presat. Water Flow (gpm)
.Outlet.Gas Temp._(eF)_
Bed Diff. (in. H20)
Demister Diff. (in. H20)
RH Diff. (in. H20)
Gas-6ttUeฑ_Elow.(in. H20)
2 "r- *7)>\ - VA- C pr
C--I f r r-\ ^ ^ I J "7 X
-ww.. _=_;.Presat Water Flow (qpm) ...
Outlet Gas Temp. (ฐF)
Bed Diff. (in. H20)
Demister Diff. (in. H20)
_ RH Diff. (in. H20)
Gas-eotTgrftow (in. IK>0)
ฃ it -r-*-... //I , fjit )
Section..^_;.Presat. Water Flow (gpm)
Outlet Gas Temp. (ฐF)
Bed Diff. (in. H20)
Demister. Diff ...(in. H20) ".
RH Diff. (in. HzO) .j
-fias-OnHet Flow (in
RH- sr pe. (
Comments
-------
CHEROKEE STATION UNIT 4 DATA SHEET
A-45
Date1:
Time:
Plant fL,et.
MM. Gross
_ xs o2
Steam Flow_Ilbs/hr _ ..
Steam Pressunpjpsvgl
Steam-Temperature
Opacity, .Bypass (%
Opacity, Scrubber
-F)
i.e*
ฃ S'*
ESP
Section Al ; AC Voltage
AC Current
nr Vnltat
DC Currei
Spark Ra
s.
te.(
Sgetinn A2; AC VO.l.tase (
AC Current 1
DC Volta
DC Curre
Spark Ra
36
it 1
te.{
Section A3; AC Voltaqe
"AC Current
DC Voltaae
DC Current
Spark Rate
Section A4: AC Volta
AC Curre
DC Volta
DC Curre
Spark Ra
qe
nt
ge
nt
te
v)
a)
Kv
ma)
spm)
v)
a),
Kv
ma) .
spm)
v)
[
I
0 la/^Q
foil /it Co/ft.
3b$
-*T3v
Jxl-n
i
Oft?
'Ou'ib Ct>f
36o
4-.j.%
olj-trt?
L
3 3 > o i jjfo
9tfO i "ti^P
3if%
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210
'/If,
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\30//ff
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-Section B1;_AC Voltage fv) \ />>ฃ
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-------
A-46
CHEROKEE STATION UNIT 4 DATA SHEET
(continued)
Scrubber
^>/77
Fans: ID Discharge Pressure (in. H?0) i-c?*f .
Fan & Outlet Pressure 1
Fan ~C Outlet Pressure
in. H20) i OUT
in. H20) /^ ;
Fan..# Outlet Pressure (in. H?01 A2 1
Fan_ ~P> Amps
Fan r Amps
. Fan ~i}~ Amps _ _. -
Jt
3-3-
_z4-
Stack Damper A, Pos. (% Opn) ! n
Stack Damper B, Pos. (% Opn) Q
Pumos: .Reel re . ..Pump .. /, ( amps
Recirc. Pump ft- amps
Recirc. Pump fa amps
Recirc. Pump fa amps
Recirc. Pump c^ amps
Recirc. Pump cป amps
Recirc. Pump _& ' amps
Recirc. Pump ~5i- amps
yj
yfe> t
/Ji '
/ฃ
/4
J/25/77
-^^
^^ 7"
/f-
/JL
-2/
-2*2
J 3>
^
0
/3
1
/(, ;
/t
/*i
/4-
f
/4- i ' /V" i
/4- ' /^
/3 / 3
Recirc. Pump Of (amps) ' 13 ' 1/3
Reheater: Steam Flow (M Ibs/hr) fay \ \ (*o
Steam Temp. (ฐF)
i
Steam Pressure (psig) /7^> :
Section 6 ; Presat. Water Flow (qpm) /-r ;
Rori niff (in. H20) ^,*
Demister Diff. (Tn. H20) /?,-? :
RH Diff. (in. H20) /.^ [ J
GasrOullel Flow
K.hf ฃft$- fSL_
te*" *ซ>
Section. .#_;_ Presat. Mater Flow (aom) _l4o
Outlet Gas Temp.
(ฐF) /60
Bed Diff. (in. H?0) , 0^7-
_wizi
/7i"
_ y^jT
6'^"
o,f
l.o
4-ปD
l<30
1 bO
OuiT
Dpmistpr niff. (in. H?0) D.J 1 J.J-
RH Pi" (in H20) fltiT ^wr
RdS OuLleL flow
TS?8*1 ซ0
^?^
1
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1
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i
Comments
-------
CHEROKEE STATION UNIT 4 DATA SHEET
A-47
Date:
Time:
'i-l
j *'Q
2JVJC J3O/Q
_U_2dL
ESP
^ Section Al; AC Voltage (v)
__~~~ ~ AC Current (a) ~~
(Kv)
230
DC Voltage
DCjCurrent (ma) JTS-J-J:?*' >'
Spark_Rate (spm)_ VZOQ ^
5-
_SectiDD_A2i_AC_Vol.tage_(v) 3-L^,,1 . c^^. 5 S
AC Current (a) _ - l_
DC Voltage (Kv)
_DC"Current (ma)
..Spark RateJ
_Sectio.n A3; AC Voltaqe
AC Current
DCT.Vol tage
DC_Current
Spark Rate
v!
a)
70
^ฃL
*"'] 4CU&-KJ
200*10
at-to
_liO.
on
ma)
spm)"
Section A4-. AC Voltaqe (v) ' ^..r . ^ป- I
AC Current (a) _ _ _ ' |
_DC Voltage (Kv) ._~ ' j"
.DC Current (ma)
Spark Rate (spm)"
_Secti on_Bl;. AC. Vol tage.
AC Current
DC_ Vol tage
DC Current
Spark Rate
v)_
a)
Kv)
ma)
spm)
ฃ70
2~>O , ?--.
3SL
IZ1]
^Si*"
305-
,-sssr
(vj .__
(a)
Section.82;.AC Voltage
AC Current
^'DC Voltage (Kv)
DC Current (ma)
Spark Rate (spm)
_Section_B3;.AC Voltage
. AC Current
DC Voltage
DC Current
Spark Rate
Section 64; AC Voltage
_ "AC Current
I__DC Voltage
... ... . DC Current
Spark Rate
!Va!
Kv)
ma)
spm)
_&0_
a
Kv
ma
spm)
) .":_."
(olO
ftOO
,05-
i Ov\
-------
CHEROKEE STATION UNIT 4 DATA SHEET
A-48
Scrubber
Fansi ID. Discharge. Pressure (in. HgO)
1 Fan B Outlet Pressure (in. H20
Fan c. Outlet Pressure (in. H20
Pan_rJ Outlet Pressure (in. H20
Fan. a" Amps
Fan c.. .Amps ....
_Fan o Amps .
, Stack Damppr A, Pos. (X Opn)
Stack Damper B. Pos. (% Opn)
Pumps: Recirc. Pump Si (amps)
Recirc.. Pump ฃz amps)
Recirc. Pump 33 amps)
Recirc. Pump c,\ amps)
Recirc. Pump 62 amps)
(continued)
|
1 -z
i zi ?? I 12 <*
j LI /ซ.-,
J.-J,- ..J^
.2 IT ->'->
0 O
o o
ป* l\
ll^ \ 'if
. l3 ,'2 S
n.j- ; /s.s-
,4. : /^
L /a.
-zee
Z20
-.'T
<"5ot-
/2.
/I.-S-
iZO-T
a^j
zs-s t r>_iT
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0 0
i
,, 13-<.
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'"'JL>
-'^
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^7
0
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/ C. i u ; /
iz s- : /z s ii
,, ^. /? ซ^
Recirc. Pump ci (amps) ,A .? ', ,A - ' , fe I /> #
^. , i f "7"" "" "
2^U i-i2 3O
/7:T /7i- /7S-
Rpd niff (in. H20) ;*.u i.1 :
Dpmister Diff. (in. H20)
RH Diff. (in. HoO) "
Gas Outlet Flow~(in. H20)
Section., b. ;. Presat. Water Flow (qpm)
Outlet r,as Temp. (ฐF)
Bed Diff. (in. H?0)
Dpmictpr niff. (in. HjO)
RH niff, (in HgO) .
Ras Outlet Flow (in. H20)
/v-"-ฐ^-
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't
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/.S ! / ฃป :
^10 4/0 !
^- / l
42O
4z c>
Comments
-------
APPENDIX B
SUMMARY OF VISIBLE EMISSION OBSERVATIONS
CHEROKEE STATION
PUBLIC SERVICE COMPANY OF COLORADO
July - August, 1977
-------
B-l
APPENDIX a
Summary of Visible Emission Observations
Unit 1 and 2 Stack - Cherokee Station
Public Service Co. of Colorado
(continued)
B-l
Date
(1977)
8/25
8/28
8/28
Time of
Observation
0734-0740
1000-1006
1014-1012
Average
Opacity
(*)
29
30
31
Opacity
Ranae
<*)
20-40
20-45
25-40
Meter*
Reading
18/16
24/12
24/12
Unit*
Load Comments*
(W)
111/100 coal/25% gas and
1A1 reel re. pump out
105/83 coal/25% gas and
1A1 reci re. pump out
105/83 coal/25% qas and
1A1 reci re. pump out
10/4 1410-1416 19 15-30 12/8 106/100 coal/coal
10/7 1000-1009 31 25-40 12/7 113/115 qas/75Z coal
10/11 1438-1447 34 30-50 12/12 115/110 coal/coal
repeater plugged
10/12 1330-1340 39 35-40 22/10 117/115 coal/coal
100% bypass
Unit 1
10/13
10/14
10/18
1045-1054
1000-1009
0910-0919
29
11
29
20-40
10-15
25-35
13/11
14/7
12/12
107/78
105/100
108/108
"01 bypass
"
t Unit 1/Uni.t 2.
-------
B-2
B-2
APPENDIX B
Summary of Visible Emission Observations
Unit 1 and 2 Stack - Cherokee Station
Public Service Co. of Colorado
Date
(1977)
7/27
7/29
7/30
8/1
8/4
8/4
8/4
8/6
8/8
8/8
8/9
8/9
8/12
8/12
8/13
8/13
8/15
8/15
8/19
8/19
8/22
C/22
8/23
8/23
8/23
8/23
8/24
8/24
8/24
8/24
8/25
Time of
Observation
1400-1406
1033-1039
1918-1924
1803-1809
1030-1036
1131-1137
1517-1523
1406-1412
1015-1021
1027-1033
1445-1451
1503-1509
1449-1455
1503-1509
1010-1016
1025-1031
1010-1017
1025-1031
1030-1036
1048-1054
1000-1006
1012-1018
1000-1006
1012-1018
1803-1809
1809-1815
1020-1026
1037-1043
1509-1515
1550-1556
0720-0726
Average
Opacity
(%)
10
22
5
26
27
32
20
21
23
23
16
22
14
11
29
29
14
18
15
6'
31
3^
29
32
21
20
30
36
32
22
30
Opaci ty
Ranne
(*)
10
10-35
5-10
15-45
20-30
25-40
20
15-25
20-30
15-35
5-30
15-40
5-30
5-40
20-40
20-40
10-20
15-20
10-20
5-10
30-35
30-35
25-40
30-40
15-30
15-30
25-35
30-45
25-40
15-30
20-40
Meter*
Reading
0/15
0/17
5/13
7/12
10/10
10/10
13/13
10/0
7/12
7/12
8/10
8/10
9/5
9/5
9/5
9/5
15/13
15/13
10/9
10/9
22/19
22/19
17/13
17/13
19/14
19/14
19/15
19/15
21/15
21/15
18/16
Unit*
Load
(W)
116/113
116/111
109/91
118/104
113/111
113/111
113/111
99/75
118/108
118/108
117/108
117/108
116/102
116/102
112/99 '
112/99
116/112
116/112
94/113
94/113
118/114
118/114
113/109
113/109
117/113
117/113
112/99
112/99
116/115
116/115
111/100
Comments1'
gas/252 gas
gas/25% gas
coal/25% gas
coal 25% qas
coal/25% gas
coal/25% gas
coal/25% gas
coal/253 gas
coal/25% gas
coal/25% gas
coal/25% gas
coal/25% qas
gas/21% gas
gas/25% gas
coal/25% gas
coal/25% qas
coal/25% gas
coal/25% gas
coal/25% gas
coal/25% gas
coal/25% gas and
1A1 reci re. pump out
coal/25% qas and
1A1 reci re. pump out
coal/25% gas and
1A1 reci re. pump out
coal/25% qas and
1A1 reci re. pump out
coal/25% gas and
1A1 reci re. pump out
coal/25^ gas and
1A1 reci re. pump out
coal/ 25% gas and
1A1 reci re. pump out
coal/25% gas and
1A1 reci re. pump out
coal/25% qas and
1A1 recirc. pump out
coal/25% gas and
1A1 recirc. pumo out
coal/25% gas and
1A1 recirc. pump out
t Unit I/Unit 2.
-------
B-3
APPENDIX B
Sunmary of Visible Emission Observations
Unit 3 Stack - Cherokee Station
Public Service Co. of Colorado
B-3
Date
(1977)
8/9
8/9
8/12
8/12
8/13
8/13
8/15
8/15
8/19
8/19
10/4
10/11
10/12
10/13
10/14
10/18
Time of
Observation
1451-1457
1509-1515
1442-1448
1510-1516
1018-1024
1033-1039
1018-1024
1032-1038
1036-1042
1054-1100
1016-1022
1029-1038
1342-1351
1054-1103
1010-1019
1009-1018
Average
Opacity
W
17
14
46
42
46
48
40
42
24
21
25
92
57
45
13
25
Opaci ty
Ranae
(X)
10-25
5-20
40-70
30-60
40-60
40-60
35-45
40-45
15-35
10-30
20-30
70-100
55-60
30-75
10-15
20-30
Meter
Reach ng
0
0
24
24
19
19
22
22
15
15
4
23
10
11
5
1
Unit
Load
(W)
136
136
130
130
129
129
132
132
140
140
108
165
103
164
155
163
Comments
Scrubber Out -
75% Gas
Scrubber Out -
75% Gas
Scrubber Out -
50% Gas
Scrubber Out -
50% Gas
Scrubber Out -
50% Gas
Scrubber Out -
50% Gas
Scrubber Out -
50% Gas
Scrubber Out -
50% Gas
Scrubber Out -
50% Gas
Scrubber Out -
50% Gas
100% Coal
3B3 Recirc.
Pump Out
75% Coal
3B Booster Fan Out
50% Bypass
50% Coal
100% Bypass
50% Coal
50% Bypass
50% Coal
50% Bypass
-------
B-4
B-4
APPENDIX B
of Visible Emission Observations
Unit 4 Stack - Cherokee Station
Public Service Co. of Colorado
Date
(1977)
7/27
7/29
7/30
8/1
8/4
8/4
8/4
8/6
8/8
8/8
8/9
8/9
8/15
8/19
8/19
8/22
8/22
8/23
8/23
8/24
8/24
8/24
8/24
8/25
8/25
8/28
8/28
10/4
10/11
10/12
10/13
10/14
10/18
Time of
Observation
1406-1411
1020-1026
1924-1930
1809-1815
1037-1043
1140-1146
1523-1528
1414-1420
1021-1027
1033-1039
1457-1503
1515-1521
1010-1017
1042-1048
1100-1106
1006-1012
1018-1024
1006-1012
1018-1024
1028-1034
1044-1050
1502-1508
1516-1522
'0727-0733
0741-0747
1007-1013
1021-1027
1022-1028
1420-1429
1352-1401
1103-1112
1019-1027
1028-1037
Average
Opacity
(ซ)
15
17
8
30
19
24
20
18
16
17
9
11
6
6
5
24
23
18
22
11
8
5
5
27
26
17
19
10
24
25
11
13
36
Opaci ty
Ranae
(ซ)
15
10-30
5-20
20-40
15-20
20-30
20
10-25
15-25
15-20
5-20
5-20
5-10
5-10
5-10
20-30
20-30
15-25
20-25
5-15
5-10
5
5-10
20-35
20-35
10-25
10-25
5-15
20-35
25
10-15
10-20
0-60
Meter
Reading
20
16
21
28
26
26
22
22
22
22
19
19
22
24
24
30
30
40
40
31
31
27
27
28
28
26
26
18
26
24
24
21
-
Unit
Load
(NO
356
358
343
314
355
355
355
348
353
353
355
355
270
355
355
358
358
360
360
362
362
355
355
362
362
262
262
190
250
241
246
230
-
Comments
Low reheat stm flow
Low reheat stm flow
Low reheat stm flow
No reheat stm
No rehea* stm
1 ESP section out
1 ESP section out
1 ESP section out
1 ESP section out
1 ESP section out
1 ESP section out
Unit start-up
-------
APPENDIX C
ELECTROSTATIC P.*ECIPITATOR DATA
AND
CALCULATIONS
CHEROKEE STATION
PUBLIC SERVICE COMPANY OF COLORADO
July - August, 1977
-------
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-------
APPENDIX D
ELECTROSTATIC PRECIPITATOR
STACK TEST SUMMARIES
CHEROKEE STATION
PUBLIC SERVICE COMPANY OF COLORADO
-------
public Service Company
P 0 BOX 840 DENVER. COLORADO 80201
October 26, 1977
gGT a 61S7T
Mr. Irwin L. Dickstein
Director, Enforcement Division
U.S. Environmental Protection Agency
Region VIII
1860 Lincoln Street
Denver, Colorado 80203
Attention: Mr. Robert Gosik, NEIC
Dear Mr. Dickstein:
Subject: Request for Information,
42 U.S. 1857c-9(a)(ii)
Reference 8E-EL
Attached is our response to your request of September 29,
1977, for particulate emission information from outlet
tests of the four Cherokee Station electrostatic precipi-
tators. The attachment complies with your request to
include stack test summaries identified by NEIC during
the September 27 meeting.
These tests were performed using various methods to
evaluate the amount of particulate emissions from the
electrostatic precipitators on each of the four Cherokee
units. Test results for unit number 2 represent particu-
late loadings entering the stack. Test results for units
number 1, 3 and 4 represent inlet grain loadings to the
scrubbers and do not represent stack particulate levels.
Srge P Green, Manager
Environmental Affairs and
Planning
attachments
cc: Mr. William Auberle, Director
Colorado Air Pollution Control Division
-------
Environmental Protection Agency
Request for Information,
42 U.S. 1857c-9(a)(ii)
October 26, 1977
Test Date
Flow Rate
Temp.
Grain Loading
Inlet Outlet
titator -
11/4/65
11/5/65
8/25/66
3/15/68
3/16/68
3/18/68
11/18/68
11/19/68
11/20/68
8/24/71
8/25/71
8/26/71
8/27/71
5/6,7/76
"
"
ACFM
Cherokee #1
528,000
537,000
508,508
517,000
532,000
519,800
555,800
550,700
549,600
516,600
515,800
491,600
~^FV~
300
300
300
287
303
289
290
295
299
298
285
296
260
260
260
gr/SCF
.647 .228
.617 .303
.3702 .2132
.220
.317
.482
.248
.386
.318
.877 .240
.943 .314
.582 .442
.529 .403
.345
.333
.337
-------
1 fironmental Protection Agency
' [uest for Information,
42 U.S. 1857c-9(a)(ii)
( :ober 26, 1977
Test Date
Flow Rate
Tem
Grain Loading
Inlet Outlet
Comments
ฐF.
gr/SCF
Lidtor - Cherokee //2
i 7/68
6/7/68
'5/68
'6/68
8/20/69
: 20/69
'17/69
12/19/69
2/70
S/5/71
1 5/71
1 5/71
W6/71
7/71
10/6/72
i/76
4/76
475,000
470,000
483,600
463,300
501,892
507,000
452,000
473,000
473,000
519,000
519,000
480,600
455,000
513,800
518,800
277
282
278
289
289
280
270
270
270
-270
286
264
292.6
295.8
.0871
.0855
.150
.178
1.47 .0835
1.28 .0840
1.117 .266
1.1205 .2658
.673 .125
.8152 .0248
.974 .0408
1.05 .0530
.990 .0623
.888 .0390
.733 .0220
.0374
.0280
Research Cottrell Test
Steam coil air heating
leak during test.
Research Cottrell Figures
PSCo Corrections to Above
Research Cottrell Tests*
Research Cottrell Tests*
Research Cottrell Tests
Research Cottrell Tests
Research Cottrell Tests
Research Cottrell Tests
* These tests are reported here for informational purposes only,
since the accuracy of the test method used is questionable.
-------
Environmental Protection Agency
Request for Information
42 U.S. 1857c-9(a)(ii)
October 26, 1977
Test Date
Flow Rate
Grain Loading
Inlet Outlet
Precipitator -
10/27/65
10/28/65
10/29/65
11/1/65
11/2/65
2/14/68
"
it
2/17/68
it
2/7/69
12/11/69
8/12/70
8/14/70
8/26/70
10/22/70
11/4/70
4/21/71
5/20/71
5/24/71
5/25/71
5/27/71
ACFM
Cherokee #3
590,800
573,600
275,000
289,500
289,500
144,200
637,100
637,100
640,000
640,000
142,887
687,500
751,700
648,800
615,000
615,000
590,500
641,300
611,100
631,700
633,000
ฐF.
292
287
285
303
296
265.5
291.2
293
294
303
287
265
295
292
296
291
gr/SCF
.192
.106
.246 .163*
.214 .203*
.182 .107*
.172*
.230
.211
.113-
.120
.712*
.212
.327 .331
.315 .330
.208 .211
.368 .179
.785 .385
.237
.523**
.615**
.490**
.593**
* One-half of precipitator tested.
** These tests were performed without gas conditioning.
-------
Environmental Protection Agency
Request for Information,
42 U.S. 1857c-9(a)(ii)
October 26, 1977
Test Date
Flow Rate
Grain Loading
Inlet Outlet
Precipitator - Cherokee
11/4/69
11/5/69
1/21/70
11
1/22/70
1/23/70
1/27/70
1/29/70
1/29/70
1/26/71
1/27/71
1/28/71
9/29/71
10/5/71
10/6/71
10/8/71
11/30/71
12/3/71
12/15/71
12/16/71
12/14/72
12/19/72
11/13/73
11/15/73
11/16/73
#4
1,421,807
1,442,966
1,390,000
1,490,000
1,490,000
1,520,000
1,530,000
1,500,000
1,510,000
1,340,000
1,226,000
1,254,000
1,484,000
1,570,000
1,506,000
1,519,000
1,490,000
1,517,000
1,557,000
1,400,000
1,407,000
1,436,000
1,325,000
1,334,000
1,425,000
ฐF.
272
271
275
280
277
269
279
275
277
278
276
277
271
268
271
244
267
265
gr/SCF
.2067
.2542
.309 .167
.297 .196
.235 .170
.270 .124
.223 .114
.142
.138
.235
.223
.278
.088
.075
.113
.171
.312*
. 405*
. 265*
.332*
.19
.212
.167
.147
.146
* These tests were performed to evaluate the precipitator performance
without gas conditioning.
-------
APPENDIX E
CALIBRATION OF BAILEY BOLOMETER
ON UNIT 2
CHEROKEE STATION
PUBLIC SERVICE COMPANY OF COLORADO
-------
E-l
APPENDIX E
CALIBRATION OF BAILEY BOLOMETER ON UNIT No. 2
A. Opacity (0) Measurements
Reading
Screen - %
Bailey Meter - %
1
2
3
4
5
6
20
40
60
80
100
6
24-25
42
60.5
78
99
B. Optical Density (O.D.)
O.D. = -log (1-0)
10
Reading
1
2
3
4
5
6
15
Screens
.097
.222
.398
.699
Bailey Meter
.027
.119-.125
.237
.403
.658
2.000
C. See Figure 16 for plot of data
-------