[Code of Federal Regulations]
[Title 40, Volume 7]
[Revised as of July 1, 2005]
From the U.S. Government Printing Office via GPO Access
[CITE: 40CFR60.G]
[Page 686]
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 Sec. 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 Sec. 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 Sec.
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 Sec.
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 Sec. 60.43(e), the owner or
operator shall conduct an initial performance test, as required by Sec.
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 Sec. 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 Sec. 60.43(e). If the owner or operator of the
affected facility elects to comply with Sec. 60.43(e) after one or more
periods of reverting to the 520 ng/J heat input (1.2 lbs/MMBTU) limit
under Sec. 60.43(a)(2), as provided under 3.4, the 30 day average
emission rate under Sec. 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 Sec. 60.43(e).
Periods of operation of the affected facility under Sec. 60.43(a)(2)
are not considered boiler operating days. Emissions data collected
during operation under Sec. 60.43(a)(2) are not considered relative to
4.6 and emissions data are not included in calculations of emission
under Sec. 60.43(e).
3.2.2 When the affected facility is operated under the provisions of
Sec. 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
Sec. 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:
[[Page 687]]
[GRAPHIC] [TIFF OMITTED] TC15NO91.206
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 Sec. 60.43(e).
E30=average emission rate for 30 successive boiler operating days where
Unit 1 and Unit 2 are subject to Sec. 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 Sec. 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 Sec. 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 Sec. 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 Sec. 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 Sec. 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 Sec. 60.11(d). However, the
general purpose contained in Sec. 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 Sec. 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:
[[Page 688]]
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 Sec. Sec. 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
[[Page 689]]
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 Sec. 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 Sec. 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
[[Page 690]]
2 under provisions of Sec. 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]