Appendix G to Part 60 - Provisions for an Alternative Method of Demonstrating Compliance With 40 CFR 60.43 for the Newton Power Station of Central Illinois Public Service Company
40:9.0.1.1.1.0.1.1.14 : Appendix G
Appendix G to Part 60 - Provisions for an Alternative Method of
Demonstrating Compliance With 40 CFR 60.43 for the Newton Power
Station of Central Illinois Public Service Company
1. Designation of Affected Facilities
1.1 The affected facilities to which this alternative compliance
method applies are the Unit 1 and 2 coal-fired steam generating
units located at the Central Illinois Public Service Company's
(CIPS) Newton Power Station in Jasper County, Illinois. Each of
these units is subject to the Standards of Performance for
Fossil-Fuel-Fired Steam Generators for Which Construction Commenced
After August 17, 1971 (subpart D).
2. Definitions
2.1 All definitions in subparts D and Da of part 60 apply to
this provision except that:
24-hour period means the period of time between 12:00
midnight and the following midnight.
Boiler operating day means a 24-hour period during which
any fossil is combusted in either the Unit 1 or Unit 2 steam
generating unit and during which the provisions of § 60.43(e) are
applicable.
CEMs means continuous emission monitoring system.
Coal bunker means a single or group of coal trailers,
hoppers, silos or other containers that:
(1) are physically attached to the affected facility; and
(2) provide coal to the coal pulverizers.
DAFGDS means the dual alkali flue gas desulfurization
system for the Newton Unit 1 steam generating unit.
3. Compliance Provisions
3.1 If the owner or operator of the affected facility elects to
comply with the 470 ng/J (1.1 lbs/MMBTU) of combined heat input
emission limit under § 60.43(e), he shall notify the Regional
Administrator, of the United States Environmental Protection Agency
(USEPA), Region 5 and the Director, of the Illinois Environmental
Protection Agency (IEPA) at least 30 days in advance of the date
such election is to take effect, stating the date such operation is
to commence. When the owner or operator elects to comply with this
limit after one or more periods of reverting to the 520 ng/J heat
input (1.2 lbs/MMBTU) limit of § 60.43(a)(2), as provided under
3.4, he shall notify the Regional Administrator of the USEPA,
Region 5 and the Director of the (IEPA) in writing at least ten
(10) days in advance of the date such election is to take
effect.
3.2 Compliance with the sulfur dioxide emission limit under §
60.43(e) is determined on a continuous basis by performance testing
using CEMs. Within 60 days after the initial operation of Units 1
and 2 subject to the combined emission limit in § 60.43(e), the
owner or operator shall conduct an initial performance test, as
required by § 60.8, to determine compliance with the combined
emission limit. This initial performance test is to be scheduled so
that the thirtieth boiler operating day of the 30 successive boiler
operating days is completed within 60 days after initial operation
subject to the 470 ng/J (1.1 lbs/MMBTU) combined emission limit.
Following the initial performance test, a separate performance test
is completed at the end of each boiler operating day Unit 1 and
Unit 2 are subject to § 60.43(e), and a new 30 day average emission
rate calculated.
3.2.1 Following the initial performance test, a new 30 day
average emission rate is calculated for each boiler operating day
the affected facility is subject to § 60.43(e). If the owner or
operator of the affected facility elects to comply with § 60.43(e)
after one or more periods of reverting to the 520 ng/J heat input
(1.2 lbs/MMBTU) limit under § 60.43(a)(2), as provided under 3.4,
the 30 day average emission rate under § 60.43(e) is calculated
using emissions data of the current boiler operating day and data
for the previous 29 boiler operating days when the affected
facility was subject to § 60.43(e). Periods of operation of the
affected facility under § 60.43(a)(2) are not considered boiler
operating days. Emissions data collected during operation under §
60.43(a)(2) are not considered relative to 4.6 and emissions data
are not included in calculations of emission under § 60.43(e).
3.2.2 When the affected facility is operated under the
provisions of § 60.43(e), the Unit 1 DAFGDS bypass damper must be
fully closed. The DAFGDS bypass may be opened only during periods
of DAFGDS startup, shutdown, malfunction or testing as described
under sections 3.5.1, 3.5.2, 3.5.3, 3.5.4, and 4.8.2.
3.3 Compliance with the sulfur dioxide emission limit set forth
in § 60.43(e) is based on the average combined hourly emission rate
from Units 1 and 2 for 30 successive boiler operating days
determined as follows:
where: n
= the number of available hourly combined emission rate values in
the 30 successive boiler operating day period where Unit 1 and Unit
2 are subject to § 60.43(e). E30 = average emission rate for 30
successive boiler operating days where Unit 1 and Unit 2 are
subject to § 60.43(e). EC = the hourly combined emission rate from
Units 1 and 2, in ng/J or lbs/MMBTU.
3.3.1 The average hourly combined emission rate for Units 1 and
2for each hour of operation of either Unit 1 or 2, or both, is
determined as follows:
EC=[(E1) + (E2)]/[H1 + H2] where: EC = the hourly combined SO2
emission rate, lbs/MMBTU, from Units 1 and 2 when Units 1 and 2 are
subject to § 60.43(e). E1 = the hourly SO2 mass emission, lb/hr,
from Unit 1 as determined from CEMs data using the calculation
procedures in section 4 of this appendix. E2 = the hourly SO2 mass
emission, lb/hr, from Unit 2 as determined from CEMs data using the
calculation procedures in section 4 of this appendix. H1 = the
hourly heat input, MMBTU/HR to Unit 1 as determined in section 4 of
this appendix. H2 = the hourly heat input, MMBTU/HR, to Unit 2 as
determined by section 4 of this appendix.
3.3.2 If data for any of the four hourly parameters (E1, E2,
H1and H2, under 3.3.1 are unavailable during an hourly period, the
combined emission rate (EC) is not calculated and the period is
counted as missing data under 4.6.1., except as provided under 3.5.
and 4.4.2.
3.4 After the date of initial operation subject to the combined
emission limit, Units 1 and 2 shall remain subject to the combined
emission limit and the owner or operator shall remain subject to
the requirements of this Appendix until the initial performance
test as required by 3.2 is completed and the owner or operator of
the affected facility elects and provides notice to revert on a
certain date to the 520 ng/J heat input (1.2 lbs/MMBTU) limit of §
60.43(a)(2) applicable separately at each unit. The Regional
Administrator of the USEPA, Region 5 and the Director, of the IEPA
shall be given written notification from CIPS as soon as possible
of CIPs' decision to revert to the 520 ng/J heat input (1.2
lbs/MMBTU) limit of § 60.43(a)(2) separately at each unit, but no
later than 10 days in advance of the date such election is to take
effect.
3.5 Emission monitoring data for Unit 1 may be excluded from
calculations of the 30 day rolling average only during the
following times:
3.5.1 Periods of DAFGDS startup.
3.5.2 Periods of DAFGDS shutdown.
3.5.3 Periods of DAFGDS malfunction during system emergencies as
defined in § 60.41a.
3.5.4 The first 250 hours per calendar year of DAFGDS
malfunctions of Unit 1 DAFGDS provided that efforts are made to
minimize emissions from Unit 1 in accordance with § 60.11(d), and
if, after 16 hours but not more than 24 hours of DAFGDS
malfunction, the owner or operator of the affected facility begins
(following the customary loading procedures) loading into the Unit
1 coal bunker, coal with a potential SO2 emission rate equal to or
less than the emission rate of Unit 2 recorded at the beginning of
the DAFGDS malfunction. Malfunction periods under 3.5.3 are not
counted toward the 250 hour/yr limit under this section.
3.5.4.1 The malfunction exemption in 3.5.4 is limited to the
first 250 hours per calendar year of DAFGDS malfunction.
3.5.4.2 For malfunctions of the DAFGDS after the 250 hours per
calendar year limit (cumulative), other than those defined in
3.5.3, the owner or operator of the affected facility shall combust
lower sulfur coal or use any other method to comply with the 470
ng/J (1.1 lbs/MMBTU) combined emission limit.
3.5.4.3 During the first 250 hours of DAFGDS malfunction per
year or during periods of DAFGDS startup, or DAFGDS shutdown, CEMs
emissions data from Unit 2 shall continue to be included in the
daily calculation of the combined 30 day rolling average emission
rate; that is, the load on Unit 1 is assumed to be zero (H1 and E1
= O; EC = E2/H2).
3.5.5-3.5.7 [Reserved]
3.6 The provision for excluding CEMs data from Unit 1 during the
first 250 hours of DAFGDS malfunctions from combined hourly
emissions calculations supersedes the provisions of § 60.11(d).
However, the general purpose contained in § 60.11(d) (i.e.,
following good control practices to minimize air pollution emission
during malfunctions) has not been superseded.
4. Continuous Emission Monitoring
4.1 The CEMs required under section 3.2 are operated and data
are recorded for all periods of operation of the affected facility
including periods of the DAFGDS startup, shutdown and malfunction
except for CEMs breakdowns, repairs, calibration checks, and zero
and span adjustment. All provisions of § 60.45 apply except as
follows:
4.2 The owner or operator shall install, calibrate, maintain,
and operate CEMs and monitoring devices for measuring the
following:
4.2.1 For Unit 1:
4.2.1.1 Sulfur dioxide, oxygen or carbon dioxide, and volumetric
flow rate for the Unit 1 DAFGDS stack.
4.2.1.2 Sulfur dioxide, oxygen or carbon dioxide, and volumetric
flow rate for the Unit 1 DAFGDS bypass stack.
4.2.1.3 Moisture content of the flue gas must be determined
continuously for the Unit 1 DAFGDS stack and the Unit 1 DAFGDS
bypass stack, if the sulfur dioxide concentration in each stack is
measured on a dry basis.
4.2.2 For Unit 2, sulfur dioxide, oxygen or carbon dioxide, and
volumetric flow rate.
4.2.2.1 Moisture content of the flue gas must be determined
continuously for the Unit 2 stack, if the sulfur dioxide
concentration in the stack is measured on a dry basis.
4.2.3 For Units 1 and 2, the hourly heat input, the hourly steam
production rate, or the hourly gross electrical power output from
each unit.
4.3 For the Unit 1 bypass stack and the Unit 2 stack, the span
value of the sulfur dioxide analyzer shall be equivalent to 200
percent of the maximum estimated hourly potential sulfur dioxide
emissions of the fuel fired in parts per million sulfur dioxide.
For the Unit 1 DAFGDS stack, the span value of the sulfur dioxide
analyzer shall be equivalent to 100 percent of the maximum
estimated hourly potential emissions of the fuel fired in parts per
million sulfur dioxide. The span value for volumetric flow monitors
shall be equivalent to 125 percent of the maximum estimated hourly
flow in standard cubic meters/minute (standard cubic feet per
minute). The span value of the continuous moisture monitors, if
required by 4.2.1.3 and 4.2.2.1, shall be equivalent to 100 percent
by volume. The span value of the oxygen or carbon dioxide analyzers
shall be equivalent to 25 percent by volume.
4.3.1-4.3.2 [Reserved]
4.4 The monitoring devices required in 4.2 shall be installed,
calibrated, and maintained as follows:
4.4.1 Each volumetric flow rate monitoring device specified in
4.2 shall be installed at approximately the same location as the
sulfur dioxide emission monitoring sample location.
4.4.2 Hourly steam production rate and hourly electrical power
output monitoring devices for Unit 1 and Unit 2 shall be calibrated
and maintained according to manufacturer's specifications. The data
from either of these devices may be used in the calculation of the
combined emission rate in section 3.3.1, only when the hourly heat
input for Unit 1 (H1) or the hourly heat input for Unit 2 (H2)
cannot be determined from CEM data, and the hourly heat input to
steam production or hourly heat input to electrical power output
efficiency over a given segment of each boiler or generator
operating range, respectively, varies by less than 5 percent within
the specified operating range, or the efficiencies of the
boiler/generator units differ by less than 5 percent. The hourly
heat input for Unit 1 (H1) or the hourly heat input for Unit 2 (H2)
in section 3.3.1 may also be calculated based on the fuel firing
rates and fuel analysis.
4.4.3-4.4.5 [Reserved]
4.5 The hourly mass emissions from Unit 1 (E1) and Unit 2 (E2)
and the hourly heat inputs from Unit 1 (H1) and Unit 2 (H2) used to
determine the hourly combined emission rate for Units 1 and 2 (EC)
in section 3.3.1 are calculated using CEM data for each respective
stack as follows:
4.5.1 The hourly SO2 mass emission from each respective stack is
determined as follows:
E = (C) (F) (D) (K) Where: E = SO2 mass emission from the
respective stack in lb per hour C = SO2 concentration from the
respective stack ppm F = flue gas flow rate from the respective
stack in scfm D = density of SO2 in lb per standard cubic feet K =
time conversion, 60 mins./hr
4.5.2 The hourly heat input from each respective stack is
determined as follows:
H=[(F) (C) (K)/(Fc) where: H = heat input from the respective stack
in MMBTU per hour C = CO2 or O2 concentration from the respective
stack as a decimal F = flue gas flow rate from the respective stack
in scfm K = time conversion, 60 mins./hr Fc = fuel constant for the
appropriate diluent in scf/MMBTU as per §§ 60.45(f) (4) and (5)
4.5.3 The hourly SO2 mass emission for Unit 1 in pounds per hour
(E1) is calculated as follows, when leakage or diversion of any
DAFGDS inlet gas to the bypass stack occurs:
E1 = (EF) + (EB) Where: EF = Hourly SO2 mass emission measured in
DAFGDS stack, lb/hr, using the calculation in section 4.5.1. EB =
Hourly SO2 mass emission measured in bypass stack, lb/hr, using the
calculation in section 4.5.1. Other than during conditions under
3.5.1, 3.5.2, 3.5.3, 3.5.4, or 4.8.2, the DAFGDS bypass damper must
be fully closed and any leakage will be indicated by the bypass
stack volumetric flow and SO2 measurements, and when no leakage
through the bypass damper is indicated: E1 = EF
4.5.4 The hourly heat input for Unit 1 in MMBTU per hour (H1) is
calculated as follows, when leakage or diversion of any DAFGDS
inlet gas to the bypass stack occurs:
H1 = (HF) + (HB) where: HF = Hourly heat input as determined from
the DAFGDS stack CEMs, in MMBTU per hour, using the calculation in
section 4.5.2 HB = Hourly heat input as determined from the DAFGDS
bypass stack CEMs, in MMBTU per hour, using the calculation in
section 4.5.2
4.6 For the CEMs required for Unit 1 and Unit 2, the owner or
operator of the affected facility shall maintain and operate the
CEMs and obtain combined emission data values (EC) for at least 75
percent of the boiler operting hours per day for at least 26 out of
each 30 successive boiler operating days.
4.6.1 When hourly SO2 emission data are not obtained by the CEMs
because of CEMs breakdowns, repairs, calibration checks and zero
and span adjustment, hourly emission data required by 4.6 are
obtained by using Methods 6 or 6C and 3 or 3A, 6A, or 8 and 3, or
by other alternative methods approved by the Regional Administrator
of the USEPA, Region 5 and the Director, of the IEPA. Failure to
obtain the minimum data requirements of 4.6 by CEMs, or by CEMs
supplemented with alternative methods of this section, is a
violation of performance testing requirements.
4.6.2 Independent of complying with the minimum data
requirements of 4.6, all valid emissions data collected are used to
calculate combined hourly emission rates (EC) and 30-day rolling
average emission rates (E30) are calculated and used to judge
compliance with 60.43(e).
4.7 For each continuous emission monitoring system, a quality
control plan shall be prepared by CIPS and submitted to the
Regional Administrator of the USEPA, Region 5 and the Director, of
the IEPA. The plan is to be submitted to the Regional Administrator
of the USEPA, Region 5 and the Director, of the IEPA 45 days before
initiation of the initial performance test. At a minimum, the plan
shall contain the following quality control elements:
4.7.1 Calibration of continuous emission monitoring systems
(CEMs) and volumetric flow measurement devices.
4.7.2 Calibration drift determination and adjustment of CEMs and
volumetric flow measurement devices.
4.7.3 Periodic CEMs, volumetric flow measurement devices and
relative accuracy determinations.
4.7.4 Preventive maintenance of CEMs and volumetric flow
measurement devices (including spare parts inventory).
4.7.5 Data recording and reporting.
4.7.6 Program of corrective action for malfunctioning CEMs and
volumetric flow measurement devices.
4.7.7 Criteria for determining when the CEMs and volumetric flow
measurement devices are not producing valid data.
4.7.8 Calibration and periodic checks of monitoring devices
identified in 4.4.2.
4.8 For the purpose of conducting the continuous emission
monitoring system performance specification tests as required by §
60.13 and appendix B, the following conditions apply:
4.8.1 The calibration drift specification of Performance
Specification 2, appendix B shall be determined separately for each
of the Unit 1 SO2 CEMs and the Unit 2 SO2 CEMs. The calibration
drift specification of Performance Specification 3, appendix B
shall be determined separately for each of the Unit 1 diluent CEMs
and Unit 2 diluent CEMs.
4.8.2 The relative accuracy of the combined SO2 emission rate
for Unit 1 and Unit 2, as calculated from CEMs and volumetric flow
data using the procedures in 3.3.1, 4.5.1, 4.5.2 and 4.5.3 shall be
no greater than 20 percent of the mean value of the combined
emission rate, as determined from testing conducted simultaneously
on the DAFGDS stack, the DAFGDS bypass stack and the Unit 2 stack
using reference methods 2, 3, or 3A and 6 or 6C, or shall be no
greater than 10 percent of the emission limit in § 60.43(e),
whichever criteria is less stringent. The relative accuracy shall
be computed from at least nine comparisons of the combined emission
rate values using the procedures in section 7 and the equations in
section 8, Performance Specification 2, appendix B. Throughout, but
only during, the relative accuracy test period the DAFGDS bypass
damper shall be partially opened such that there is a detectable
flow.
4.8.3-4.8.3.4 [Reserved]
4.9 The total monitoring system required by 4.2 shall be subject
only to an annual relative accuracy test audit (RATA) in accordance
with the quality assurance requirements of section 5.1.1 of 40 CFR
part 60, appendix F. Each SO2 and diluent CEMs shall be subject to
cylinder gas audits (OGA) in accordance with the quality assurance
requirements of section 5.1.2 of appendix F with the exception that
any SO2 or diluent CEMs without any type of probe or sample line
shall be exempt from the OGA requirements.
5. Recordkeeping Requirements
5.1 The plant owner or operator shall keep a record of each
hourly emission rate, each hourly SO2 CEMs value and hourly flow
rate value, and each hourly Btu heat input rate, hourly steam rate,
or hourly electrical power output, and a record of each hourly
weighted average emission rate. These records shall be kept for all
periods of operation of Unit 1 or 2 under provisions of § 60.43(e),
including operations of Unit 1 (E1) during periods of DAFGDS
startup, shutdown, and malfunction when H1 and E1 are assumed to be
zero (0) (see 4.5).
5.2 The plant owner or operator shall keep a record of each
hourly gas flow rate through the DAFGDS stack, each hourly stack
gas flow rate through the bypass stack during any periods that the
DAFGDS bypass damper is opened or flow is indicated, and reason for
bypass operation.
6. Reporting Requirements
6.1 The owner or operator of any affected facility shall submit
the written reports required under 6.2 of this section and subpart
A to the Regional Administrator of the USEPA, Region 5 and the
Director, of the IEPA for every calendar quarter. All quarterly
reports shall be submitted by the 30th day following the end of
each calendar quarter.
6.2 For sulfur dioxide, the following data resubmitted to the
Regional Administrator of the USEPA, Region 5 and the Director, of
the IEPA for each 24-hour period:
6.2.1 Calendar date
6.2.2 The combined average sulfur dioxide emission rate (ng/J or
lb/million Btu) for the past 30 successive boiler operating days
(ending with the last 30-day period in the quarter); and, for any
noncompliance periods, reasons for noncompliance with the emission
standards and description of corrective action taken.
6.2.3 Identification of the boiler operating days for which
valid sulfur dioxide emissions data required by 4.6 have not been
obtained for 75 percent of the boiler operating hours; reasons for
not obtaining sufficient data; and description of corrective
actions taken to prevent recurrence.
6.2.4 Identification of the time periods (hours) when Unit 1 or
Unit 2 were operated but combined hourly emission rates (EC) were
not calculated because of the unavailability of parameters E1, E2,
H1, or H2 as described in 3.2.
6.2.5 Identification of the time periods (hours) when Unit 1 and
Unit 2 were operated and where the combined hourly emission rate
(EC) equalled Unit 2 (E2/H2) emissions because of the Unit 1
malfunction provisions under 3.5.3, and 3.5.4.
6.2.6 Identification of the time periods (hours) when emissions
from the Unit 1 DAFGDS have been excluded from the calculation of
average sulfur dioxide emission rates because of Unit 1 DAFGDS
startup, shutdown, malfunction, or other reasons; and justification
for excluding data for reasons other than startup or shutdown.
Reporting of hourly emission rate of Unit 1 (E1/H2) during each
hour of the DAFGDS startup, malfunction under 3.5.1, 3.5.2, 3.5.3,
and 3.5.4 (see 4.5).
6.2.7 Identification of the number of days in the calendar
quarter that the affected facility was operated (any fuel
fired).
6.2.8 Identify any periods where Unit 1 DAFGDS malfunctions
occurred and the cumulative hours of Unit 1 DAFGDS malfunction for
the quarter.
6.2.9 Identify any periods of time that any exhaust gases were
discharged to the DAFGDS bypass stack and the hourly gas flow rate
through the DAFGDS stack and through the DAFGDS bypass stack during
such periods and reason for bypass operation.
6.2.10 [Reserved]
[52 FR 28955, Aug. 4, 1987, as amended at 58 FR 28785, May 17,
1993; 59 FR 8135, Feb. 18, 1994]