Oklahoma Gas & Electric Muskogee Generating Station Best ...

Oklahoma Gas & Electric
Muskogee Generating Station – BART Determination
May 28, 2008
Table 4-3 continued:
Control
Technology
Wet FGD with
WESP
Dry FGD – Spray
Dryer Absorber
Dry Sorbent
Injection
Circulating Dry
Scrubber
SO2 Emission Rate
In Service on
Existing PC
Boilers?
(lb/mmBtu) Yes No
NA X
0.10 lb/mmBtu
(approx. 50 ppmvd @
3% O2)
0.4 lb/mmBtu
(approx. 200 ppmvd
@ 3% O2)
X
X
NA X
49
In Service on
Other
Combustion
Sources?
The WESP control
system is in use at
a limited number of
high-sulfur coal-
fired units.
In use on sub-
bituminous coal-
fired boilers.
Dry sorbent
injection has been
used on a limited
number of coalfired
units.
CDS is in use at a
limited number of
coal-fired boilers.
Step 3: Rank the Technically Feasible SO2 Control Options by Effectiveness
Technically Feasible Retrofit
Technology for Muskogee Units
4 & 5?
Not technically feasible nor
commercially available for units
firing a low-sulfur subbituminous
coal.
Technically feasible.
Technically feasible, but not as
effective as other SO2 control
options therefore excluded as
BART.
CDS Dry FGD was determined
not to be commercially available
for Muskogee Units 4 & 5 (large
sub- bituminous fired units). In
addition, there is no commercial
experience with units similar to
Muskogee Units 4 & 5, so CDS-
DFGD was excluded as BART.
Both technically feasible SO2 retrofit technologies (i.e., Wet- and Dry-FGD) are capable of meeting
the BART presumptive level of 0.15 lb/mmBtu. However, in order to evaluate the cost
effectiveness of each control technology, annual emissions and costs were estimated at the design
emission limits of 0.08 lb/mmBtu for WFGD and 0.10 lb/mmBtu for DFGD. This approach was
taken in order to determine whether either control technology was cost effective at the anticipated
design emission rate. The technically feasible SO2 control technologies are listed in Table 4-4 in
descending order of control efficiency based on anticipated design emission rates.